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Home My WebLink About200-1967. 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 thes 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 S-104 Install Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-196 50-029-22988-00-00 ADL 0028258 9196 Conductor Surface Intermediate Production Liner 7159 80 3708 9159 8724 20" 9-5/8" 7" 7065 29 - 109 28 - 3736 26 - 9186 2750 29 - 109 28 - 2863 26 - 7149 8719, Unknown 520 3090 5410 8724 1530 5750 7240 6920 - 8840 4-1/2" 12.6# L-80 24 - 87365046 - 6807 Structural 4-1/2" Baker S3 Packer 4-1/2" Baker SABL-3 Packers (3) 6853, 4988 7061, 5169 / 7201, 5291 / 8679, 6647 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY 9/30/2025 Current Pools: POLARIS OIL / Aurora Oil Proposed Pools: POLARIS OIL / Aurora Oil 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 By Grace Christianson at 12:45 pm, Sep 15, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.15 12:33:14 - 08'00' Torin Roschinger (4662) 325-561 AOGCC witnessed MITIA once on stabilized injection. SFD 9/16/2025 DSR-9/24/25 X 10-404 , ADL 0028257 SFD JJL 9/24/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.24 15:34:13 -08'00'09/24/25 RBDMS JSB 092625 Reset Patch on Injector Well: S-104 PTD: 200-196 API: 50-029-22988-00 Well Name:S-104 Permit to Drill:200-196 Current Status:Not Operable API Number:50-029-22988-00 Estimated Start Date:9/30/2025 Estimated Duration:2day Regulatory Contact:Abbie Barker Service Lines:SL/EL/FB First Call Engineer:Hunter Gates (215) 498-7274 (M)(907) 777-8326 (O) Second Call Engineer:Tyson Shriver (406) 690-6385 (M) Brief Well Summary: S-104 recently received an AA to operate with TxIA communication by maintaining IA pressure by periodic bleeds. However, recently we've seen more rapid TxIA repressurization. We only see the repressurization on MI not PWI, and since the MIT-IA passed to 3,582 psi (packer has integrity), the small gas leak likely is originating from either the patch or one of the DGLV's with extended packing. The patch has been pulled and will allow us to reset the extended packing DGLV’s. From here, we will reset the patch to cover the historic tubing leak. Current Status: Shut-In – Not Operable, WAG injector Pressure/Integrity History 6/16/2025 – AA approved for TxIA 7/3/2025 – PPPOT-T passed 7/7/2025 - MIT-IA Passed to 3582 psi Procedure Slickline 1. MIRU SL. Drift to X-nipple at 6,842’ MD. 2. POOH and RIH to set nipple reducer in X-nipple at 6,842’ MD. 3. POOH and RIH to set XX plug in nipple reducer. Set X-catcher on top of plug. 4. Pull DGLV’s from Station #4 and #5. 5. RIH to set new extended packing DGLV’s in both stations. 6. Pull catcher. 7. Secure well. RDMO SL. E-line/Fullbore 1. MIRU EL. 2. MU logging tools and RIH w/ Temp/CCL and pull baseline pass from 6,600’ MD to 6,300’ MD. Then pump down IA and pull secondary pass across same interval to verify leak point. 3. POOH and MU single trip straddle patch and correlate to leak. Anticipated leak point to be about 6,481’ MD. Set patch to straddle leak point once depth is confirmed. 4. Utilize pump truck to pressure up against packer and plug to verify good set. Conduct MIT-T to 2500 psi. 5. RDMO EL. Slickline 1. MIRU SL. RIH and pull plug from X-nipple at 6,842’ MD. 2. RDMO and turn well over to production to put back online. Attachments: x Procedure x Current Wellbore Schematic x Proposed Wellbore Schematic x Sundry Change Form Reset Patch on Injector Well: S-104 PTD: 200-196 API: 50-029-22988-00 Current Wellbore Schematic: Reset Patch on Injector Well: S-104 PTD: 200-196 API: 50-029-22988-00 Proposed Wellbore Schematic: New Single Trip Patch covering leak @ 6,481’ MD Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: September 15, 2025Subject: Changes to Approved Sundry Procedure for Well S-104Sundry #: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 ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-104 Pull Tubing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-196 50-029-22988-00-00 9196 Conductor Surface Intermediate Production Liner 7159 80 3708 9159 8724 20" 9-5/8" 7" 7065 29 - 109 28 - 3736 26 - 9186 29 - 109 28 - 2863 26 - 7149 8719, Unknown 520 3090 5410 8724 1530 5750 7240 6920 - 8840 4-1/2" 12.6# L-80 24 - 8736 5046 - 6807 Structural 4-1/2" Baker S3 Packer 7061, 5169 / 7201, 5291 / 8679, 6647 6853, 7061, 7201, 8679 4988, 5169, 5291, 6647 Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com 907-777-8326 PRUDHOE BAY, POLARIS OIL / PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028258 24 - 6704 N/A N/A Well Not Online 3726 1425 140 3050 400 N/A 13b. Pools active after work:Polaris OIL 4-1/2" Baker SABL-3 Packers (3) 6853, 4988 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 8:40 am, Aug 28, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.28 06:21:24 - 08'00' Torin Roschinger (4662) RBDMS JSB 090425 DSR-9/11/25J.Lau 11/6/25 ACTIVITY DATE SUMMARY 8/2/2025 (TFS unit 1 assist S-Line with Load) Traveled to location. ****WSR Continued on 8-3- 2025***** 8/2/2025 ***WELL S/I ON ARRIVAL*** RAN 3.80" GAUGE RING TO PATCH AT 6,430' SLM/ 6,455' MD (all clear) RAN 3-1/2" 42 BO TO RJ RELEASE JOINT IN PATCH AT 6,457' SLM (good indications - see log) JARRED ON PATCH AT 6,455' MD FOR 1 HR (no movement) ***CONTINUE ON 8/3/25 WSR*** 8/3/2025 ****WSR Continued from 8-2-2025***** (TFS unit 1 Assist S-Line with TBG load) Pumped 280 bbls of DSL and 281 bbls of KCL down the TBG to attempt to Kill the well. Pumped a further 50 bbls of DSL down the TBG for FP. Called off job for SL maintenance. Well left in S-Line control. Final WHPS 1700/1750/0 8/3/2025 ***CONTINUE FROM 8/2/25 WSR*** JARRED ON PATCH AT 6,455' MD FOR 2.5 HRS S-BOX PKG ISSUE- (hole tbg 8480MD- unable to bleed to zero) LOAD & KILL WELL POLLARD UNPLANNED MAINT ***CONTINUE ON 8/4/25 WSR*** 8/4/2025 ***CONTINUED FROM 8/3/25 WSR*** JARRED ON PATCH AT 6,455' MD FOR 6 HRS (~6' of movement since yesterday) ***CONTINUE ON 8/5/25 WSR*** 8/5/2025 ***CONTINUED FROM 8/4/25 WSR*** JARRED ON PATCH AT 6,455' MD FOR 1 HR (no further movement- RJ release issue? looking for B-shifting tool w/ selective key) ***WELL LEFT S/I ON DEPARTURE*** 8/7/2025 ***(TFS U4 assist SL)*** Job continues to 8/825 8/7/2025 ***WELL S/I ON ARRIVAL*** R/U .160 ***CONTINUED ON 8-8-25*** 8/8/2025 ***(TFS U4 assist S-line)*** Pumped 3 bbls of 50/50, followed by 225 bbls KCL down the TBG to load, followed with 50 bbls of DSL for FP. EWHP=1650/1829/0 S/L in control of well Upon Departure. 8/8/2025 ***CONTINUED FROM 8-7-25*** T-BIRD LOADED TBG w/ 200 bbls KCL, 40 bbls DIESEL F/P PULLED UPPER SECTION OF N.S. 2 TRIP STRADDLE (missing 2.5 elements). RAN 4 1/2" BRUSH AND 3 PRONGED WIRE GRAB TO 6458' SLM. RECOVERED 1 MISSING ELEMENT. RAN 4 1/2" BRUSH, AND 3 PRONGED WIRE GRAB TO 6458' SLM. NO RECOVERY. RAN 4 1/2" GS TO 6458' SLM. JARRED ON LOWER PATCH ASSY 2600 - 3000# FOR 53 MINS; RECOVERED QCLL RATCHET ASSY (30" OAL). ***CONTINUED ON 8-9-25*** Daily Report of Well Operations PBU S-104 Daily Report of Well Operations PBU S-104 8/9/2025 ***CONTINUED FROM 8-8-25*** RAN 3.70" OLD STYLE SPEAR w/ 3.44" GRAPPLE TO LOWER PATCH SECTION (recovered serrated band from ratchet system) PLANTED 3.70" OLD STYLE SPEAR IN LOWER PATCH SECTION @ 6,460' SLM. JARRED ON LOWER PATCH ASSY 2400 - 3200# FOR 7 HOURS W/ NO MOVEMENT. ***CONTINUED ON 8-10-25*** 8/10/2025 ***CONTINUED FROM 8-9-25*** JARRED ON LOWER PATCH ASSY FOR 4.5 HRS @ 3200# W/ NO MOVEMENT (11.5 hrs total) PULLED 3.70" OLD STYLE RELEASABLE SPEAR FROM LOWER PATCH ASSY. SPEAR LOOKED GOOD. DECISION MADE TO RIG DOWN & WILL RETURN TO PLANT A YELLOW JACKET ITCO SPEAR FOR COIL ***JOB NOT COMPLETE / WILL RETURN*** 8/14/2025 ***WELL S/I ON ARRIVAL*** RUN 4-1/2" GR W/ YELLOW JACKET TT9145 NON RELEASABLE ITCO SPEAR. PLANT SPEAR IN LOWER HALF OF NORTHERN PATCH @ 6,481' MD. (GRAPPLE RANGE: 3.297" - 3.392") SHEAR GR. POOH. RUN 4-1/2" GS & JAR ON PATCH 30 MINS TO MAKE SURE SPEAR IS PLANTED. SHEAR OFF. RIG DOWN. ***WELL S/I ON DEPARTURE / COIL IS UP NEXT*** 8/15/2025 LRS CTU 2, 1.75" x .156" HT-110. Job Objective: Fish NS Patch Rig up CTU 2. Make up 3.13" fishing BHA with 4" hydraulic GS. Load well with 1% KCl and large meth spears in front and behind. Latch into patch and perfom 1 jar lick before hydraulic issues on the unit. POOH and repair. ...Continued on 8-16-25... 8/16/2025 LRS CTU #2 -1.75" Long String Job Objective: Pull Patch RIH with 3-1/8" fishing BHA with 4" hydraulic GS. Latch lower packer at 6468' CTMD. PAtch free on 3rd jar lick, however heavy drag and overpulls at each tubing collar. Attempt to shuck slip/element but still have consistent overpulls. Pulling into GLM #5 and become detained at 4790' CTMD. After heavy jaring and pumping down the backside, pop free and unable to latch. POOH and unable to shut the master. RIH and drop of fish @ 4798' CTM. ***Fish left in hole.*** ***Job Complete*** Daily Report of Well Operations PBU S-104 8/17/2025 ***WELL S/I ON ARRIVAL*** PULLED PATCH AT 4,791' SLM & RECOVERED 24' 7" OF THE LOWER HALF OF THE NORTHERN BIG BORE PATCH. PATCH WAS PARTED RIGHT ABOVE THE NORTHERN PACKER ~ 5 INCHES BELOW WHERE THE 3-1/2" STL SPACER PIPE SCREWS INTO THE PACKER. ~ 5FT OF PACKER STILL IN HOLE. ATTEMPT TO RECOVER ELEMENTS WITH A 4-1/2" & 3.25" BRUSH (recovered both metal rings) ATTEMPT TO GET ELEMENTS WITH 3.50" WIRE GRAB (no recovery) ***CONTINUE ON 8/18/25*** 8/18/2025 ***CONTINUE FROM 8/17/25*** SET 45KB SPEAR AT 4,820' SLM JARRED ON PACKER FISH @ 4,818' SLM FOR 3 HRS w/ .125 C SWAPPED TO .160" WIRE PERFORM FIRE DRILL w/ DAY CREW & WSS JARRED ON PACKER FISH @ 4,818' SLM FOR 4.5 HRS w/ .160 C ***CONTINUE ON 8/19/25*** 8/19/2025 ***CONTINUE FROM 8/18/25*** JARRED ON PACKER FISH @ 4,818' SLM FOR 3 HRS w/ .160" (7.5 hrs total @ 3200#) RELEASED AND PULLED 45 KB SPEAR FROM PACKER FISH RAN 4-1/2" GR & PLANTED YJ TT 9145 ITCO SPEAR IN PACKER @ 4,819' SLM (grapple = 2.784 - 2.81", oal = 34") RAN 4-1/2" GS & JAR @ 3200# FOR 30 MINS TO CONFIRM SPEAR SET FOR COIL ***WELL S/I ON DEPARTURE, COIL UP NEXT*** 8/21/2025 LRS CTU #2 - 1.75" Long String Job Objective: Fish packer. MIRU CTU, Spot Equipment and R/U, Function test BOPS Cont on WSR 8/22/25 8/22/2025 LRS CTU #2 - 1.75" Long String Job Objective: Fish packer. Test BOPS, M/U YJ CTC and Fishing BHA with 4" GS. RIH and latch spear at 4841' CTMD. Begin jarring and pull spear from packer. Replace with larger grapple (2.891") and RIH. Plant spear and begin fishing. Recover heavily deformed inner mandrel (well pictures info) with multiple parts and lower sub remaining in GLM #5 at 4839' MD. RIH with Venturi Jet Basket to attempt suck up any debris. ***Job In Progress*** Daily Report of Well Operations PBU S-104 8/23/2025 LRS CTU #2 - 1.75" Long String Job Objective: Fish packer. Cont RIH with YJ 2-7/8" Motor and 3.80' Bullnose Junk Mill, Tag @4844' CTM, Start milling and able to move packer debris and bottom sub. Work though mandrels and sleeves and push sub down to the PX Prong, leaving the top at 8719' MD (8727' CTMD). POOH and FP tubing with diesel. Rig down CTU. ***Job Complete**** ****Due to tags and overpulls at the sleeves, especially station #2 and the sleeve at 7175' MD, there may be a large amount of packer debris and cuttings in the jewelry. Consider brushing mandrels to ensure clean and confirm all sleeves are closed.***** 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: WAG Injector S-104 (PTD #2001960) TxIA communication Date:Monday, July 28, 2025 8:41:37 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, July 27, 2025 8:01 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: NOT OPERABLE: WAG Injector S-104 (PTD #2001960) TxIA communication Mr. Wallace, A PPPOT-T passed to 5,000 psi on 07/03. An offline MIT-IA passed to 3,582 psi on 07/07/25. The result of these tests point to a possible one-way leak and the most likely culprit would be the existing tubing patch or one of the DGLVs. Our plan is to pull the tubing patch, replace the extended packing DGLVs and then replace the tubing patch. Since this work will require a Sundry, the well will now be classified as NOT OPERABLE until the work is completed. 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 2, 2025 11:16 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: WAG Injector S-104 (PTD #2001960) TxIA communication Mr. Wallace, WAG Injector S-104 (PTD #2001960) currently operates under AA AIO 22F.003 for TxIA communication while on MI. On 07/01/25, the well was reported to have climbed to ~1,800 psi and was bled twice within 24 hours. The increase of bleed frequency indicates a change in the mechanical condition and the well has been shut-in per the AA. It is now classified as UNDER EVALUATION for up to 28-days for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. 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 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. 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: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717T40717PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' 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: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 21, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-104 PRUDHOE BAY UN AURO S-104 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2025 S-104 50-029-22988-00-00 200-196-0 G SPT 4988 2001960 3150 3007 3009 3010 3013 25 40 41 41 OTHER P Austin McLeod 5/30/2025 MITIA to MAIP. Under evaluation. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S-104 Inspection Date: Tubing OA Packer Depth 433 3799 3727 3709IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250531175945 BBL Pumped:3.2 BBL Returned:3.2 Monday, July 21, 2025 Page 1 of 1           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: WAG Injector S-104 (PTD #2001960) TxIA communication Date:Wednesday, July 2, 2025 12:49:14 PM Attachments:S-104.pdf TIOChart.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, July 2, 2025 11:16 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: WAG Injector S-104 (PTD #2001960) TxIA communication Mr. Wallace, WAG Injector S-104 (PTD #2001960) currently operates under AA AIO 22F.003 for TxIA communication while on MI. On 07/01/25, the well was reported to have climbed to ~1,800 psi and was bled twice within 24 hours. The increase of bleed frequency indicates a change in the mechanical condition and the well has been shut-in per the AA. It is now classified as UNDER EVALUATION for up to 28-days for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Fullbore: Offline MIT-IA 3. 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 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"CM/ WELLHEAD = FMC ACTUATOR= LEO OKB. E3.EV = 64.50 BF_ R = 3822' KOP= 750' Max Angle = 57` @ 3230' Datum MD = 879T Datum TVD= 6700'SS 19-5/8" CSG, 40#, L-80 BTC, D = 8.835" I- 3736' CONFIRM AOGCC APPROVAL WITH OE & RE PRIORTO ANY COMMINGLED INJECTION. COMMINGLED INJECTION MUST COMPLY WITH AID 22F AND CO 484A. 7" MARKERJT(20') W/ RA TAG I� 4-1/2" TBG JT #40 W/ RA TAG Minimum ID = 2.313" @ 8724' 2-7/8" NIPPLE REDUCER PERFORATION SUMMARY REF LOG: SWS PLATFORM EXPRESS GR/RES ON 01/27/01 ANGLEAT TOP PERF: 8' @ 8790' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 4-518" 6 6920 - 6980 O 02/04/01 4-5/8" 6 7018 - 7050 O 02/04/01 4-5/8" 6 7070 - 7094 O 02/04/01 4-5/8" 6 7114 - 7124 O 02/04/01 4-5/8" 6 7162 - 7182 O 02/04/01 4-5/8" 6 7216 - 7266 O 02/04/01 4-5/8" 6 7280 - 7302 O 02/04/01 4-518" 6 7325 - 7346 O 02/04/01 2-7/8" 6 8790 - 8810 C 11/05/14 3-318" 6 8810 - 8840 C 0326/01 3-318" 6 8816 - 8836 C 05/01/03 4-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf , D = 3.958" FISH - 2-718" LOCATOR DOG 1"x2.5" (02/0621) — S-104 SAFETY NOTES: 112S READINGS AVERAGE 125 ppm WHEN ON MI — WELL REQUIRES A SSS V WHEN ON MI 1008' 9-5/8" TAM PORT COLLAR 2403' 4-1/2" HES X NP, D = 3.813" 42' N5 UPPLK PA I GH, (/11520) NS BIG BORE LWR PATCH. D =2.81' 3-12' X NIP, ID = 2.81" GAS LIFT MANDRELS STI MD I ND I DEV I TYPE I VLV I LATCH I PORT I DATE 5 4 4839 6731 3495 4883 54 31 KBG2-T/L KBG2-T/L *DMY 'DAM I BK BK 1 0 0 10/1724 12/27/24 *STA 95 & #4 = EXTENDED PACKING R4-1/24 H 1 7266 5347 30 KBG2--T/L i+iF-V *BK I MAX 08/01Y24 �Te f lk " R 1K = •fl:al YnMRM r1K I A Tr4 .11 n 111-I" 7175' I—I4-12" BKR CMU SLD SLV, OTIS PROF, ID= 3.812" SCHRADER - POLARIS AUTHORIZED ID= 3,875" 7333' —14-12' BKR CMU SLD SLV, OTIS PROF, ID = 3.812' 86�-17" X 4-12" BKR SABL-3 RCP, D= 3.875" 4-12" HES X NIP, ID = 3.813" 4-12' HES XN NIP, ID = 3.725" 8724 -�4-12" X 2-7/8" NIP REDUCER, ID = 2.313" (12620) 8724 2-7/8" PX RUG AND PRONG (07/31/24) 8736' 8736' 4-12' WLEG, ID = 4.00' ELMD TT NOT LOGGED KUPARUK-AURORA AUTHORIZED FOR WAG INJECTION PBTD 9100' = 6.276" 9186' DATE REV BY OOMVENTS DATE REV BY COMU134TS 02109/01 NOES ORIGINAL COMPLETION 08/08/23 NLW/J WFR CJO (072323) 0720/20 NXW/J PULLED XX RUG (07/12120) 06/20/24 WRUM) PULLED MCX RUG (06/1524) 072020 EPD/JMJ SET LWR PATCH w /X NP (07/1320) 08/06/24 WRUM) SET PX PLUG & PRONG (07/31124) 072120 JCIJMID+ SET UPPER PATCH (07/1820) 08/O6/24 JTG/JM) WFR CJO (08/0124) 08/15/20 JKC(I M SET PLUG & PRONG (08/13120) 10/29/24 JTG/JM) GLV CJO (10117124) 02/1721 TD'MM CO DMY P PRONG w / WFRV. FISH 01/17/25 JPK/JMD GLV CIO (1227/24) AURORA IMF WELL S-104 PERMIT No: t001960 AP ND: 50-029-22988-00 T12K R12E, 4646' NSL & 4494' Hilcorp North Slope, LLC Well: S-1114 r 4,s0o 4,s0o 4,400 4,200 4,000 3,9D0 3,&00 3,400 3,200 3,000 ZE 0 2,&00 2,400 2,200 2,000 1,800 1,&00 1,400 1,200 1,000 am Gm 400 21k 04107J25 04,'09125 0411 &+25 04i23)25 05+07125 M14125 05i21125 0 ■ — 30a 290 230 270 2&0 250 240 230 220 210 200 190 130 170 1fi0 3 150 m m 140 m 130 120 110 100 90 30 70 fi0 50 40 3D 20 10 TIO Plot f Tubing — On ■ Bleed * Operable + Not Oper ♦ Under Eval Man. IA —� Man. OA Man. OOA Man. OOOA O Man. WHT 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: WAG Injector S-104 (PTD #2001960) AA for slow TxIA communication Date:Monday, June 16, 2025 3:23:43 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, June 16, 2025 2:46 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector S-104 (PTD #2001960) AA for slow TxIA communication Mr. Wallace, Injector S-104 (PTD 2001960) has been approved by the AOGCC for continued WAG injection with slow TxIA communication with AIO 22F.003 and AIO 25A.030. The well is now classified as OPERABLE. Please call 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 From: PB Wells Integrity Sent: Monday, May 26, 2025 6:15 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; 'jim.regg' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: WAG Injector S-104 (PTD #2001960) Slow TxIA communication Mr. Wallace, Injector S-104 (PTD # 2001960) appears to have slow TxIA communication post extended DGLV install in February that cannot be attributed to injection rate or temperature. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan forward: 1. Fullbore: AOGCC MIT-IA 2. Well Integrity: Evaluate for corrective action / AA 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: Monday, March 31, 2025 7:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; jim.regg <jim.regg@alaska.gov> Subject: WAG Injector S-104 (PTD #2001960) IA bleed Mr. Wallace, Injector S-104 (PTD # 2001960) IA pressure was bled from 900 psi to 200 psi with all liquid returns on 03/28. The IA pressure has increased slightly since the bleed however gas injection temperature and rate is not static. We will continue to monitor IA pressure and if we determine there is TxIA communication, the well will be made under evaluation. Please call with any questions or concern. 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: Sunday, February 2, 2025 10:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: OPERABLE: WAG Injector S-104 (PTD #2001960) IA re-pressurization resolved All, Injector S-104 (PTD # 2001960) DGLV with extended packing in sta 4 was set on 12/27/24. The well was placed on MI on 12/28/24 and there has been no IA re-pressurization or bleed event since. The well is now classified as OPERABLE. 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: Monday, January 6, 2025 10:48 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to establish injectivity into the well once CDR2 has moved off of S-100, and then place on MI and monitor for TxIA communication. The under evaluation clock has now been reset. Please call 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 From: PB Wells Integrity Sent: Monday, December 9, 2024 11:25 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to put S-104 on MI once the rig is off M-207. The under evaluation clock has now been reset. 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: Sunday, November 10, 2024 5:46 PM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan forward is to put S-104 back on water after the rig is off M- 206 and then put the well back on gas after the rig is complete on M-207. The under evaluation clock has now been reset. 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: Monday, October 14, 2024 5:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics to allow for continued work on S-104 as the rig is now off S-119. The under evaluation clock has now been reset. 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: Monday, September 16, 2024 4:48 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: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization All, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250602 (IGB 25-001) Well API #PTD #Log Date Log Company Log Type Format AOGCC E-Set# KTU 43-6XRD2 50133203280200 205117 07/14/2014 POLLARD CBL PDF MPU C-15A 50029213580100 216070 07/06/2016 HALLIBURTON RCBL PDF LAS PPTX PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR PDF TIF PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT PCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL PDF TIF Please include current contact information if different from above. T40515 T40516 T40517 T40518 T40519 T40520 T40521 T40522 PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.03 08:26:36 -08'00' 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: UNDER EVALUATION: WAG Injector S-104 (PTD #2001960) Slow TxIA communication Date:Tuesday, May 27, 2025 8:25:37 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, May 26, 2025 6:15 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: UNDER EVALUATION: WAG Injector S-104 (PTD #2001960) Slow TxIA communication Mr. Wallace, Injector S-104 (PTD # 2001960) appears to have slow TxIA communication post extended DGLV install in February that cannot be attributed to injection rate or temperature. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan forward: 1. Fullbore: AOGCC MIT-IA 2. Well Integrity: Evaluate for corrective action / AA 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: Monday, March 31, 2025 7:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; jim.regg <jim.regg@alaska.gov> Subject: WAG Injector S-104 (PTD #2001960) IA bleed Mr. Wallace, Injector S-104 (PTD # 2001960) IA pressure was bled from 900 psi to 200 psi with all liquid returns on 03/28. The IA pressure has increased slightly since the bleed however gas injection temperature and rate is not static. We will continue to monitor IA pressure and if we determine there is TxIA communication, the well will be made under evaluation. Please call with any questions or concern. 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: Sunday, February 2, 2025 10:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: OPERABLE: WAG Injector S-104 (PTD #2001960) IA re-pressurization resolved All, Injector S-104 (PTD # 2001960) DGLV with extended packing in sta 4 was set on 12/27/24. The well was placed on MI on 12/28/24 and there has been no IA re-pressurization or bleed event since. The well is now classified as OPERABLE. 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: Monday, January 6, 2025 10:48 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to establish injectivity into the well once CDR2 has moved off of S-100, and then place on MI and monitor for TxIA communication. The under evaluation clock has now been reset. Please call 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 From: PB Wells Integrity Sent: Monday, December 9, 2024 11:25 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to put S-104 on MI once the rig is off M-207. The under evaluation clock has now been reset. 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: Sunday, November 10, 2024 5:46 PM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan forward is to put S-104 back on water after the rig is off M- 206 and then put the well back on gas after the rig is complete on M-207. The under evaluation clock has now been reset. 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: Monday, October 14, 2024 5:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics to allow for continued work on S-104 as the rig is now off S-119. The under evaluation clock has now been reset. 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: Monday, September 16, 2024 4:48 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: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization All, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: WAG Injector S-104 (PTD #2001960) IA bleed Date:Tuesday, April 1, 2025 8:41:53 AM Attachments:S-104.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, March 31, 2025 7:44 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: WAG Injector S-104 (PTD #2001960) IA bleed Mr. Wallace, Injector S-104 (PTD # 2001960) IA pressure was bled from 900 psi to 200 psi with all liquid returns on 03/28. The IA pressure has increased slightly since the bleed however gas injection temperature and rate is not static. We will continue to monitor IA pressure and if we determine there is TxIA communication, the well will be made under evaluation. Please call with any questions or concern. 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: Sunday, February 2, 2025 10:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: OPERABLE: WAG Injector S-104 (PTD #2001960) IA re-pressurization resolved All, Injector S-104 (PTD # 2001960) DGLV with extended packing in sta 4 was set on 12/27/24. The well was placed on MI on 12/28/24 and there has been no IA re-pressurization or bleed event since. The well is now classified as OPERABLE. 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: Monday, January 6, 2025 10:48 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to establish injectivity into the well once CDR2 has moved off of S-100, and then place on MI and monitor for TxIA communication. The under evaluation clock has now been reset. Please call 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 From: PB Wells Integrity Sent: Monday, December 9, 2024 11:25 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to put S-104 on MI once the rig is off M-207. The under evaluation clock has now been reset. 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: Sunday, November 10, 2024 5:46 PM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan forward is to put S-104 back on water after the rig is off M- 206 and then put the well back on gas after the rig is complete on M-207. The under evaluation clock has now been reset. 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: Monday, October 14, 2024 5:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics to allow for continued work on S-104 as the rig is now off S-119. The under evaluation clock has now been reset. 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: Monday, September 16, 2024 4:48 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: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization All, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WAG Injector S-104 (PTD #2001960) IA re-pressurization resolved Date:Monday, February 3, 2025 8:09:26 AM Attachments:S-104.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 2, 2025 10:37 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> Subject: OPERABLE: WAG Injector S-104 (PTD #2001960) IA re-pressurization resolved Mr. Wallace, Injector S-104 (PTD # 2001960) DGLV with extended packing in sta 4 was set on 12/27/24. The well was placed on MI on 12/28/24 and there has been no IA re-pressurization or bleed event since. The well is now classified as OPERABLE. 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: Monday, January 6, 2025 10:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to establish injectivity into the well once CDR2 has moved off of S-100A, and then place the well on MI and monitor for TxIA communication. The under evaluation clock has now been reset. Please call with any questions or concerns. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, January 6, 2025 10:41 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Oliver, Your request for an additional 28 days 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: Monday, January 6, 2025 10:39 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>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was placed on MI for IA repressurization evaluation on 12/28/24. Prior to the well being swapped to MI, it was on PWI and showed no signs of IA repressurization. Currently the well is failing to take MI rate and requires fullbore to execute a HOT treatment to establish injectivity. The CDR2 rig is currently on S-100A, limiting access to S-104, so this treatment cannot be executed currently. The rig is expected to complete operations by 1/9/25, at which time the necessary work on S-104 can be executed. With permission, we would like to extend the under evaluation period for an additional 28 days to execute the HOT and evaluate for possible TxIA on MI . Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, December 9, 2024 11:25 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to put S-104 on MI once the rig is off M-207. The under evaluation clock has now been reset. 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: Friday, November 8, 2024 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has remained shut in since the rig left on S-119. An extended packing DGLV was run on 10/18. With permission, we would like to extend the under evaluation period for an additional 28 days with the well on water until we can get back on MI to evaluate the TxIA. 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: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, October 10, 2024 11:14 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Ryan, Your reequest for 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: Thursday, October 10, 2024 10:26 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; 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. Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was reported for possible TxIA communication on 09/16 and like S- 122, has been blocked by the rig on S-119 for planned well intervention. With permission, I would like to request an additional 28 days under evaluation starting on 10/14 (when the original 28 day clock is set to expire). The rig on S-119 is planning to move in the next day or so. 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: Monday, September 16, 2024 4:30 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Tuesday, January 7, 2025 3:45:36 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, January 6, 2025 10:52 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>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to establish injectivity into the well once CDR2 has moved off of S-100A, and then place the well on MI and monitor for TxIA communication. The under evaluation clock has now been reset. Please call 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 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, January 6, 2025 10:41 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Oliver, Your request for an additional 28 days 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: Monday, January 6, 2025 10:39 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>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was placed on MI for IA repressurization evaluation on 12/28/24. Prior to the well being swapped to MI, it was on PWI and showed no signs of IA repressurization. Currently the well is failing to take MI rate and requires fullbore to execute a HOT treatment to establish injectivity. The CDR2 rig is currently on S-100A, limiting access to S-104, so this treatment cannot be executed currently. The rig is expected to complete operations by 1/9/25, at which time the necessary work on S-104 can be executed. With permission, we would like to extend the under evaluation period for an additional 28 days to execute the HOT and evaluate for possible TxIA on MI . Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity Sent: Monday, December 9, 2024 11:25 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan is to put S-104 on MI once the rig is off M-207. The under evaluation clock has now been reset. 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: Friday, November 8, 2024 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has remained shut in since the rig left on S-119. An extended packing DGLV was run on 10/18. With permission, we would like to extend the under evaluation period for an additional 28 days with the well on water until we can get back on MI to evaluate the TxIA. 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: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, October 10, 2024 11:14 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> 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. Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Ryan, Your reequest for 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: Thursday, October 10, 2024 10:26 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was reported for possible TxIA communication on 09/16 and like S- 122, has been blocked by the rig on S-119 for planned well intervention. With permission, I would like to request an additional 28 days under evaluation starting on 10/14 (when the original 28 day clock is set to expire). The rig on S-119 is planning to move in the next day or so. 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: Monday, September 16, 2024 4:30 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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. 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:PB Wells Integrity Cc:Regg, James B (OGC); Oliver Sternicki Subject:RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Monday, December 9, 2024 10:52:56 AM Ryan, Your request for additional 28 days injection for 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: Wednesday, December 4, 2024 8:17 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> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) remains on water injection with no sign of TxIA communication. The rig is currently scheduled to be complete on M-207 around 12/12, after which S-104 can be put on MI injection for continued diagnostics. The current 28 day under evaluation period on S-104 ends on 12/09. With your approval, we would like to request an additional 28 days of injection starting on 12/09 for continued diagnostics. 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: Sunday, November 10, 2024 5:46 PM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan forward is to put S-104 back on water after the rig is off M- 206 and then put the well back on gas after the rig is complete on M-207. The under evaluation clock has now been reset. 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: Monday, October 14, 2024 5:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics to allow for continued work on S-104 as the rig is now off S-119. The under evaluation clock has now been reset. 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: Monday, September 16, 2024 4:48 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: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization All, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Wednesday, December 4, 2024 8:52:23 AM Attachments:S-104.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, December 4, 2024 8:17 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> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) remains on water injection with no sign of TxIA communication. The rig is currently scheduled to be complete on M-207 around 12/12, after which S-104 can be put on MI injection for continued diagnostics. The current 28 day under evaluation period on S-104 ends on 12/09. With your approval, we would like to request an additional 28 days of injection starting on 12/09 for continued diagnostics. 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: Sunday, November 10, 2024 5:46 PM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics on S-104. The current plan forward is to put S-104 back on water after the rig is off M- 206 and then put the well back on gas after the rig is complete on M-207. The under evaluation clock has now been reset. 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: Monday, October 14, 2024 5:37 AM To: PB Wells Integrity <PBWellsIntegrity@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 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization All, Injector S-104 (PTD # 2001960) AOGCC has approved an additional 28 days of monitoring and diagnostics to allow for continued work on S-104 as the rig is now off S-119. The under evaluation clock has now been reset. 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: Monday, September 16, 2024 4:48 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: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization All, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Tuesday, November 12, 2024 8:06:50 AM From: Wallace, Chris D (OGC) Sent: Sunday, November 10, 2024 4:01 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Ryan, Your request for 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: Friday, November 8, 2024 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has remained shut in since the rig left on S-119. An extended packing DGLV was run on 10/18. With permission, we would like to extend the under evaluation period for an additional 28 days with the well on water until we can get back on MI to evaluate the TxIA. 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 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: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, October 10, 2024 11:14 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Ryan, Your reequest for 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: Thursday, October 10, 2024 10:26 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was reported for possible TxIA communication on 09/16 and like S- 122, has been blocked by the rig on S-119 for planned well intervention. With permission, I would like to request an additional 28 days under evaluation starting on 10/14 (when the original 28 day clock is set to expire). The rig on S-119 is planning to move in the next day or so. 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: Monday, September 16, 2024 4:30 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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. 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Sunday, November 10, 2024 4:00:57 PM From: Wallace, Chris D (OGC) Sent: Sunday, November 10, 2024 4:01 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Ryan, Your request for 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: Friday, November 8, 2024 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has remained shut in since the rig left on S-119. An extended packing DGLV was run on 10/18. With permission, we would like to extend the under evaluation period for an additional 28 days with the well on water until we can get back on MI to evaluate the TxIA. 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 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: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, October 10, 2024 11:14 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Ryan, Your reequest for 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: Thursday, October 10, 2024 10:26 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was reported for possible TxIA communication on 09/16 and like S- 122, has been blocked by the rig on S-119 for planned well intervention. With permission, I would like to request an additional 28 days under evaluation starting on 10/14 (when the original 28 day clock is set to expire). The rig on S-119 is planning to move in the next day or so. 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: Monday, September 16, 2024 4:30 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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. 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-104 PRUDHOE BAY UN AURO S-104 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 S-104 50-029-22988-00-00 200-196-0 G SPT 4988 2001960 1500 2748 2754 2753 2754 15 21 22 21 4YRTST P Adam Earl 8/9/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S-104 Inspection Date: Tubing OA Packer Depth 6 1847 1748 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812131811 BBL Pumped:3.4 BBL Returned:2 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 999 99 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 14:49:07 -08'00' 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: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Thursday, October 10, 2024 11:14:55 AM From: Wallace, Chris D (OGC) Sent: Thursday, October 10, 2024 11:14 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Ryan, Your reequest for 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: Thursday, October 10, 2024 10:26 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re- pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) was reported for possible TxIA communication on 09/16 and like S- 122, has been blocked by the rig on S-119 for planned well intervention. With permission, I would like to request an additional 28 days under evaluation starting on 10/14 (when the original 28 day clock is set to expire). The rig on S-119 is planning to move in the next day or so. 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: Monday, September 16, 2024 4:30 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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, 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. 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 EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Date:Tuesday, September 17, 2024 7:45:03 AM Attachments:S-104.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 16, 2024 4:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATON: WAG Injector S-104 (PTD #2001960) anomalous IA re-pressurization Mr. Wallace, Injector S-104 (PTD # 2001960) has been flagged for possible TxIA communication. The well was recently put on miscible gas injection and passed an AOGCC witnessed MIT-IA on 08/09/24. An IA pressure bleed was performed on 09/05/24 and since that bleed the pressure has slowly climbed. The well will now be classified as UNDER EVALUATON and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs. 3. 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 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. 4-1/16" CIW WELLHEAD= FMC ACTUATOR= LM OKB. R = 64.59 BF. R = 38 2-7 KOP= 750' Max Angle = 57' @ 3230' Datum MD = 879T Datum TVD= 6700'SS 19-5/8" CSG, 40#, L-80 BTC, D = 8.835" I— 3736' CONFIRM AOGCC APPROVAL WITH OE & RE PRIORTO ANY COMMINGLED INJECTION. COMMINGLED INJECTION MUST COMPLY WITH AID 22F AND CO 484A. 7" MARKE3RJT (20') W/ RA TAG 649W 4-12" TBG JT#40 W/ RA TAG 668V Minimum ID = 2.313" @ 8724' 2-7/8" NIPPLE REDUCER PERFORATION SUMMARY REF LOG: SWS PLATFORM D(PRESS GR(RES ON 01/27/01 ANGLEAT TOP PERF: 8" @ 8790' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 4-5/8" 6 6920 - 6980 O 02/04/01 4-5/8" 6 7018 - 7050 O 02/04/01 4-5/8" 6 7070 - 7094 O 02/04/01 4-5/8" 6 7114 - 7124 O 02/04/01 4-5/8" 6 7162 - 7182 O 02/04/01 4-5/8" 6 7216 - 7266 O 02/04/01 4-5/8" 6 7280 - 7302 O 02/04/01 4-518" 6 7325 - 7346 0 02/04/01 2-7/8" 6 8790-8810 C 11/05/14 3-318" 6 8810 - 8840 C 03/26/01 3-318" 6 8816 - 8836 C 05/01/03 4-1/2" TBG, 12.6#, L-80 NSCT, H .0152 bpf , D = 3.958" I ` FISH - 2-7/8" LOCATOR DOG t"x2.5" (02106/21) — S-104 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI'"" WELL REQUIRES A SSSV WHEN ON MI 1008' 9-5/8" TAM PORT COLLAR 2403' 4-12" HES X NP, D = 3.813" I U' N5 UPPEK PA ICH, (7/1620) NS BIG BORE LWR PATCH, D =2.81' 3-12" X NIP, ID = 2.81" r_Ac1r uw AI STI MDjTVDj DEVI TYPE I VLV ILATCH PORT DATE 5 4 483E 6731 3495 4883 54 31 1 KBW-T/L KBG2-T/L I DMY DMY I BK BK 0 0 05/10/02 05/10/02 7" X 4-12" BKR S-3 PKR, ID = 3.875" IAI IC!`T Kl \IA nmoo Q ST MD TVD DEVI TYPE VLV ILATCH PORT DATE 3 5046 29 KBG2111- L-WF "BK 430 2 �6920 7117 5218 30 KI3G2-T/L L-WF 'BK 585 �08/01124 08/01/24 1 7266 5347 30 KBG2-T/L F-1NF 'BK MAX 08MI24 = MID MUMFI® SK LATCHES w/ EXTENSION: -1/2" BKR CMU SLD SLV, OTIS PROF., D = 3.812" 7061' l-17" X 4-l2- BKR SABL-3 WK D = 3.875- 7175' 4-12" BKR CMU SLD SLV, OTIS PROF, ID = 3.812" SCHRADER - POLARIS AUTHORIZED ID = 3.875" 7333' —j4-12" BKR CMU SLD SLV, OTIS PROF, ID = 3.812' 867�-17" X 4-1/2" BKR SABL-3 WK D= 3.875" 4-12" HES X NIP, ID = 3.813" 4-12" HES XN NIP, ID = 3.725" $724 -�4-12" X 2-7/8" NIP REDUCER, ID = 2.313" (12620) 8724 2-7/8- PX RUG AND PRONG (07131124) 8736' 8736' 4-12' WLEG, ID = 4.00' ELMD TTNOTLOGGED KUPARUK-AURORA AUTHORIZED FOR WAG INJECTION PBTD 9100' DATE REV BY COMMENTS DATE REV BY COM134TS 02109/01 N9ES ORIGINAL COMPLETION 08/08/23 NLW/JIVU VVFIR G0 (072323) 072020 NXV#JM1 PULLED XX RUG (07/1220) 0620/24 WR/JMD PULLED MC)( PLUG (06/1524) 072020 EPDiJMD SET LWR PATCH w/)( NIP (07/13120) 08/06/24 WR/JMD SET P)( PLUG & PRONG (0713124) 072120 JC(JMD+ SET UPPER PATCH (07/1820) 08/06/24 JTG/JMD VVFR C/O (08/0124) 08/1520 JKC/Mu1 SET PLUG & PRONG (08/13120) 02M 721 TDI M1 CO DMY P PRONG w / WFRV. FISH DH. AURORA UNIT WELL: S-104 PERMIT No: F2001960 API No: 50-029-22988-00 f12N, R12E, 4649 NSL & 4494' VA Hilcorp North Slope, LLC l , 24 1 i.2- U Well: 5-104 0 0--a 68/11/24 W1&24 0&2524 09i01,24 III 300 290 ■ 280 270 260 250 240 230 220 210 200 190 180 170 160 03 150 n 140 e 130 120 110 100 90 80 70 so 50 40 30 20 10 0911524 TIO Plo f Tubinc_ —On ■ Bleed Operal + Not OF ♦ Under Man. I, -A Man. C Man. C —♦ Man. C -A3- Man. 4 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: 9/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240912 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 7/22/2024 BAKER RPM Blossom 1 50133206480000 215015 8/31/2024 READ Coilflag Blossom 1 50133206480000 215015 9/2/2024 READ MemoryRadialCementBondLog KBY 43-07Y 50133206250000 214019 9/9/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/29/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/4/2024 AK E-LINE Plug/Perf NCIU A-20 50883201960000 224065 8/29/2024 AK E-LINE Perf NCIU A-20 50883201960000 224065 9/3/2024 AK E-LINE Plug/Perf PBU N-21A (REVISED) 50029213420100 196196 3/28/2024 BAKER SPN PBU N-02 50029200830000 170055 7/25/2024 BAKER SPN PBU S-104 50029229880000 200196 7/7/2024 BAKER SPN PBU Z-68 50029234930000 213093 7/6/2024 BAKER SPN Pearl 11 50133207120000 223032 6/24/2024 BAKER SPN Revision explanation: OmniView .las file was the same as the carbo/oxygen .las file, omniview file has been replaced with the correct file and data. Please include current contact information if different from above. T39545 T39546 T39546 T39547 T39548 T39548 T39549 T39549 T39550 T39551 T39552 T39553 T39554 PBU S-104 50029229880000 200196 7/7/2024 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.12 12:52:42 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-104 Isolate Aurora Oil Pool Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-196 50-029-22988-00-00 9196 Conductor Surface Intermediate Production Liner 7159 80 3708 9159 8724 20" 9-5/8" 7" 7065 29 - 109 28 - 3736 26 - 9186 29 - 109 28 - 2863 26 - 7149 Unknown 520 3090 5410 8724 1530 5750 7240 6920 - 8840 4-1/2" 12.6# L-80 24 - 8736 5046 - 6807 Structural 4-1/2" Baker S3 Packer 7061, 5169 / 7201, 5291 / 8679, 6647 6853, 7061, 7201, 8679 4988, 5169, 5291, 6647 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, POLARIS OIL / PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028258 24 - 6704 N/A N/A 2776 4396 0 0 1856 2804 N/A 13b. Pools active after work:AURORA OIL 4-1/2" Baker SABL-3 Packers (3) 6853, 4988 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.22 07:21:41 - 08'00' Torin Roschinger (4662) By Grace Christianson at 8:55 am, Aug 22, 2024 RBDMS JSB 082824 DSR-8/26/24WCB 10-3-2024 ACTIVITY DATE SUMMARY 7/29/2024 TFS Unit 1 Assist SL Did not pump any Fluid ***JOB CONTINUES*** 7/29/2024 ***WELL S/I ON ARRIVAL*** BRUSHED 4-1/2" x 2-7/8" NIP REDUCER @ 8724' MD SET 2-7/8" PX PLUG BODY(4 x 3/16" ports, 23" LIH) IN 4-1/2" x 2-7/8" NIP REDUCER 8724' MD SET P-PRONG (84'' x 1.50'' body, 1.375'' fn) IN PX PLUG BODY @ 8724' MD ***WSR CON ON 7-30-24*** 7/30/2024 T/I/O=600/0/0 TFS Unit 1 Assist Slickline Pumped a total of 2 BBLS 50/50, 93 BBLS of 1% KCL and 32.5 BBLS to Assist Slickline downhole with Waterflood valves. Attempted to Freeze Protect Tubing pumped 24 BBLS of DSL down hole before reaching our MAP of 1450. Will finish DSL FP as job Continues Per SL WSL. ***JOB CONTINUES*** 7/30/2024 ***WSR CONT FROM 7-29-24*** SET 3-1/2" WHIDDON C-SUB ON TOP OF P-PRONG @ 8724' MD PULLED BK(w/ ext btm sub) MAX FLOW WFR FROM STA #3 @ 6920' MD SET BK(w/ ext btm sub) DGLV IN STA #3 @ 6920' MD PULLED BK(w/ ext btm sub) MAX FLOW WFR FROM STA #2 @ 7117' MD SET BK(w/ ext btm sub) DGLV IN STA #2 @ 7117' MD PULLED BK(w/ ext btm sub) MAX FLOW WFR FROM STA #1 @ 7266' MD T-BIRD FP TBG 21BBLS DIESEL OF THE 40BBLS (tight zone) SET BK(w/ ext btm sub) DGLV IN STA #1 @ 7266' MD ***WSR CONT ON 7-31-24*** 7/31/2024 ***JOB CONTINUE from 7-30-2024*** TFS Unit 1 Assist Slickline Pumped a total of 30 BBLS of DSL to assist Slickline. Established a LLR of 0.5 BPM at 1980 psi at 0030 am. Then further assistance through-out the day established another LLR of 0.5 BPM at 1520 PSI at 2030 pm. ***JOB CONTINUE*** 7/31/2024 ***WSR CONT FROM 7-30-24*** PULLED 3-1/2'' WHIDDON FROM 8686' SLM (empty) SET 3-1/2'' WHIDDON @ 8692' SLM RAN (x2) KJ, 3-1/2" OK-1(alum ext finger), 7" EXT, 3" EXT, JK RUNNING TOOL w/ TATTLE PINS, UNABLE TO LOC OR S/D ON ANY STATIONS. PULLED 3-1/2" WHIDDON C-SUB FROM 8686' SLM (empty) PULLED P-PRONG FROM 2-7/8" PX PLUG BODY @ 8724' MD (pking in good shape) PULLED 2-7/8" PX PLUG BODY FROM 4-1/2" x 2-7/8" NIP REDUCER @ 8724' MD (pking in good shape) SET 2-7/8" PX PLUG BODY(4 x 3/16" ports, 23" LIH) @ 8724' MD SET P-PRONG (84'' x 1.50'' body, 1.375'' fn) IN PX PLUG BODY @ 8724' MD ATTEMPTED PT PLUG TO 2000#psi, LLR OF .5 BPM @ 1520#psi FOR 5BBLS (see t-bird log) ***WSR CONT ON 8-1-24*** Daily Report of Well Operations PBU S-104 (gg ) SET 2-7/8" PX PLUG BODY(4 x 3/16" ports, 23" LIH) @ 8724' MD SET P-PRONG (84'' x 1.50'' body, 1.375'' fn) IN PX PLUG BODY @ 8724' MD ()@ Daily Report of Well Operations PBU S-104 8/1/2024 ***WSR CONT FROM 7-31-24*** RAN HES LDL PER PROGRAM (good data), LEAKS FOUND @ 6920' & 8480' MD NO FLOW OBSERVED GOING PAST PLUG IN NIPPLE REDUCER @ 8724' MD ON LDL CONFIRMING KUPARUK PERFORATIONS ARE ISOLATED AND INJECTION WILL ONLY BE GOING INTO THE SCHRADER INTERVAL, SET 3-1/2" WHIDDON C-SUB ON P-PRONG @ 8691' SLM PULLED BK(w/ ext btm sub)-DGLV FROM STA #3 @ 6920' MD SET STA #3 BK(w/ ext btm sub)-WFR(16/64", 1 spacer, 430 BWPD) @ 6920' MD PULLED BK(w/ ext btm sub)-DGLV FROM STA #2 @ 7117'' MD SET STA #2 BK(w/ ext btm sub)-WFR(18/64", no spacer, 585 BWPD) @ 7117' MD PULLED ST#1 BK(w/ ext btm sub)-DGLV FROM 7266' MD SET STA #1 BK(w/ ext btm sub)-WFR(24/64", no spacer, 909 BWPD-MAX) 7266' MD ***WSR CONT ON 8-2-24*** 8/1/2024 ***JOB CONTINUES from 7-31-2024*** TFS Unit 1 assist SL Pumped a total of 31.5 BBLS of DSL to assist Slickline during the day setting and pulling valves. ***JOB CONTINUES to 8-2-2024*** 8/2/2024 ***WSR CONT FROM 8-1-24*** PULLED 3-1/2'' WHIDDON CATCHER FROM 8687' SLM (empty) RAN HES 24 ARM CALIPER FROM 8685' SLM TO SURFACE (good data) ***PAD OP NOTIFIED OF WELL STATUS, WELL LEFT S/I ON DEPARTURE*** 8/2/2024 ***JOB CONTINUES from 8-1-2024*** TFS Unit 1 Assist Slickline did not pump any fluid. Slickline in control of well upon departure. FWHP=1020/0/0 8/9/2024 T/I/O = 2748/6/15 AOGCC MIT-IA PASSED to 1740 psi (Witnessed by AOGCC Inspector Adam Earl) Pumped 3.4 bbls of 120* diesel down IA to reach achieve test pressure of 1847 psi. IA lost 99 psi first 15 mins and lost 8 psi second 15 mins for a total loss of 107 psi in 30 mins. Bled back 2 bbls. FWHP = 2754/103/17 Pad Op notified upon departure. RAN HES LDL PER PROGRAM (good data), LEAKS FOUND @ 6920' & 8480' MD(g )@ NO FLOW OBSERVED GOING PAST PLUG IN NIPPLE REDUCER @ 8724' MD@ ON LDL CONFIRMING KUPARUK PERFORATIONS ARE ISOLATED AND INJECTION WILL ONLY BE GOING INTO THE SCHRADER INTERVAL, 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 S-104 (PTD #2001960) Due for 4 year compliance testing Date:Friday, August 2, 2024 11:54:16 AM Attachments:image001.pngimage002.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, August 2, 2024 6:37 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: OPERABLE: Injector S-104 (PTD #2001960) Due for 4 year compliance testing Mr. Wallace, Injector S-104 (PTD # 2001960) logging is complete and isolation plug has been set at 8724’ to prevent comingled injection. The well is now classified as OPERABLE and will require an AOGCC MIT-IA once thermally stable on injection. 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: Thursday, July 4, 2024 4:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector S-104 (PTD #2001960) Due for 4 year compliance testing Mr. Wallace, Injector S-104 (PTD # 2001960) is shut in for upcoming e-line logging with MCX removed. The well is due this month for online AOGCC witnessed 4 year MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in until logging is complete and the well will require a witnessed online MIT-IA when put back on injection. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Sunday, July 19, 2020 9:12 AM To: Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW-GC2-WellpadS@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Tyler Norene <Tyler.Norene@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com> Subject: OPERABLE: Injector S-104 (PTD #2001960) Patch re-set, passed MIT-IA All, Injector S-104 (PTD # 2001960) was made Not Operable on 06/06/19 after it failed a MIT-IA. A Leak Detect Log discovered a leak in the production tubing at 6501’ MD below an old patch set at 6463’-6495’ MD. The patch was pulled and re-set on 07/18/20 from 6455’-6505’ MD as outlined in Sundry #319-324. A passing MIT-IA to 2,401 psi was performed on 07/18/20. The passing MIT-IA confirms the well has two competent barriers to formation and will now be classified as OPERABLE. Please note the fluid packed annulus when putting the well on injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: AK, GWO Well Integrity Engineer Sent: Thursday, June 6, 2019 8:49 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Thompson, Ryan <RYAN.THOMPSON@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Subject: NOT OPERABLE: Injector S-104 (PTD #2001960) TxIA communication confirmed with failing MIT-IA All, Injector S-104 (PTD #2001960) was made under evaluation on 5/9/2019 for having anomalous inner annulus repressurization. On 5/10/2019 DHD performed a failing MIT-IA confirming TxIA communication and the well was shut in and freeze protected on 5/13/2019. Further diagnostics and repair have been delayed by the Kuparuk river bridge outage. The UE period is now expired and the well is reclassified as Not Operable. Plan Forward: 1. Slickline – Secure well, Leak detection log 2. Production Engineer – Evaluate for repair Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 9, 2019 7:35 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Thompson, Ryan <RYAN.THOMPSON@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector S-104 (PTD #2001960) Anomalous inner annulus repressurization after bleed All, Injector S-104 (PTD #2001960) was identified as having anomalous inner annulus repressurization on 5/9/2019 during a routine UIC bleed. The repressurization indicates a potential failure of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Wellhead – PPPOT-T 2. DHD – MIT-IA 3. Well Integrity Engineer – Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 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, 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 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 considersappropriate. 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 S-104 (PTD #2001960) Due for 4 year compliance testing Date:Friday, July 5, 2024 9:01:20 AM Attachments:image001.pngimage002.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, July 4, 2024 4:26 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 S-104 (PTD #2001960) Due for 4 year compliance testing Mr. Wallace, Injector S-104 (PTD # 2001960) is shut in for upcoming e-line logging with MCX removed. The well is due this month for online AOGCC witnessed 4 year MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in until logging is complete and the well will require a witnessed online MIT-IA when put back on injection. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Sunday, July 19, 2020 9:12 AM To: Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW-GC2-WellpadS@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Tyler Norene <Tyler.Norene@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com> Subject: OPERABLE: Injector S-104 (PTD #2001960) Patch re-set, passed MIT-IA All, Injector S-104 (PTD # 2001960) was made Not Operable on 06/06/19 after it failed a MIT-IA. A Leak Detect Log discovered a leak in the production tubing at 6501’ MD below an old patch set at 6463’-6495’ MD. The patch was pulled and re-set on 07/18/20 from 6455’-6505’ MD as outlined in Sundry #319-324. A passing MIT-IA to 2,401 psi was performed on 07/18/20. The passing MIT-IA confirms the well has two competent barriers to formation and will now be classified as OPERABLE. Please note the fluid packed annulus when putting the well on injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: AK, GWO Well Integrity Engineer Sent: Thursday, June 6, 2019 8:49 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Thompson, Ryan <RYAN.THOMPSON@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Subject: NOT OPERABLE: Injector S-104 (PTD #2001960) TxIA communication confirmed with failing MIT-IA All, Injector S-104 (PTD #2001960) was made under evaluation on 5/9/2019 for having anomalous inner annulus repressurization. On 5/10/2019 DHD performed a failing MIT-IA confirming TxIA communication and the well was shut in and freeze protected on 5/13/2019. Further diagnostics and repair have been delayed by the Kuparuk river bridge outage. The UE period is now expired and the well is reclassified as Not Operable. Plan Forward: 1. Slickline – Secure well, Leak detection log 2. Production Engineer – Evaluate for repair Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 9, 2019 7:35 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Duong, Lea <Lea.Duong@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Thompson, Ryan <RYAN.THOMPSON@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector S-104 (PTD #2001960) Anomalous inner annulus repressurization after bleed All, Injector S-104 (PTD #2001960) was identified as having anomalous inner annulus repressurization on 5/9/2019 during a routine UIC bleed. The repressurization indicates a potential failure of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Wellhead – PPPOT-T 2. DHD – MIT-IA 3. Well Integrity Engineer – Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity EngineerOffice: 907-659-8110 Cell: 907-341-9068 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, 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 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 considersappropriate. 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: 09/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230920 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPI 2-68 50029218580000 188097 9/11/2023 READ Caliper Survey PBU S-104 50029229880000 200196 9/5/2023 READ IPROF Revision explanation: PBU S-210: Updated LAS files and Final Report added. Please include current contact information if different from above. T38004 T38005 9/21/2023 PBU S-104 50029229880000 200196 9/5/2023 READ IPROF Kayla Junke Digitally signed by Kayla Junke Date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y Jody Colombie at 1:58 pm, Feb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allace, Chris D (CED) From: Roby, David S (CED) Sent: Friday, January 22, 2021 12:31 PM To: Brian Glasheen; Oliver Sternicki Cc: Rixse, Melvin G (CED); Boyer, David L (CED); Wallace, Chris D (CED) Subject: RE: [EXTERNAL] Sundry application to downhole commingle injection in PBU S-104 (PTD 200-196) Brian, Yes, that allocation process will work. Yes, for this well if you ever do switch to MI you will either need to close off one of the zones or apply for authorization to downhole commingle the MI, assuming that is that pool wide commingled injection hadn't already been approved and included MI. Regards, Dave Roby 907-793-1232 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 thise-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 Dave Roby at 907- 793-1232 or dave.robvc@alaska.zov. From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Friday, January 22, 202112:14 PM To: Roby, David S (CED) <dave.roby@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Boyer, David L (CED) <david. boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Subject: RE: [EXTERNAL] Sundry application to downhole commingle injection in PBU S-104 (PTD 200-196) Dave, Yes currently only injecting water. The Schrader has WFRV and we have a known rate at a known WHP (-550 bwpd @ 1600psi). We plan to maintain the same WHP with both zones open and will allocate that volume to the Schrader. Will suffice that allocation side of things? Oliver and I will continue to work the pool wide application as we will likely see more of these in the future. If we ever consider MI we can isolate the zones individually? Will that work for you guys? Thanks Brian Glasheen Operations Engineer 907-545-1144 Wallace, Chris D (CED) From: Roby, David S (CED) Sent: Thursday, January 21, 2021 4:32 PM To: Brian Glasheen Cc: Rixse, Melvin G (CED); Boyer, David L (CED); Wallace, Chris D (CED) Subject: Sundry application to downhole commingle injection in PBU S-104 (PTD 200-196) Brian, 20 AAC 25.215 prohibits the downhole commingling of injection in a wellbore unless, after public notice and opportunity for comment/hearing the AOGCC determines it won't cause waste and the injection volumes can be allocated between the pools and issues an order authorizing it. No such order has been issued for the subject well, so Hilcorp will need to submit an application for downhole commingling that addresses the issue in 20 AAC 25.115(c)(1). We have previously authorized commingled injection between the Borealis and POP and the Aurora and POP on a pool wide basis, but not between the Schrader and Aurora, so if you think commingled injection between the Schrader and Aurora is something you'll pursue in additional wells in the future you may want to seek pool wide authorization instead of an order that applies only to the S-104 well so we only have to go through the notice and hearing process once instead of for each individual well. Let me know if you have any questions. Regards, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robvCdalaska.zov. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:200-196 6.API Number:50-029-22988-00-00 PRUDHOE BAY, AURORA OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028257 & 028258 Property Designation (Lease Number):10. 341 8. PBU S-104 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Comingle Injection Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9196 Effective Depth MD: L-80 11. 2/3/2021 Commission Representative: 15. Suspended Contact Name: Brian Glasheen Contact Email: brian.glasheen@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Baker SABL-3 Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 7159 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 6853, 4988 Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 28 - 3736 28 - 2863 14. Estimated Date for Commencing Operations: BOP Sketch 29 - 109 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 6920 - 8840 5046 - 6807 4-1/2" 12.6#24 - 8736 Production 8724 6692 8724 None 29 - 109 520 9-5/8" Contact Phone:(907)564-5277 Date: 80 153020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3707 5750 Intermediate 9160 7" 26 - 9186 26 - 7149 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2913 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. No SSSV Installed 7061, 5169 / 7201, 5291 / 8679, 6647 By Samantha Carlisle at 8:40 pm, Jan 20, 2021 321-043 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.01.20 15:56:18 -09'00' Stan Golis (880) 10-404 Well must be operated, and injection allocated, as described in 1/22/21 email from HNS to AOGCC. DLB 01/21/2021 X DSR-1/22/21MGR21JAN21 Yeson Required? C 1/28/21 dts 1/28/2021 JLC 1/28/2021 RBDMS HEW 1/29/2021 Well: S-104 PTD:200-196 API: 50-029-22988-00 Well Name:S-104 API Number:50-029-22988-00 Current Status:Online injecting AFE PO Estimated Start Date:01/28/2021 Estimated Duration:1 day Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker 564-4915 First Call Engineer:Brian Glasheen (907) 564-5277 (O)(907) 545-1144 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3583 psi@ 6700’ TVD (FL shot 9/28/2018 from the Kuparuk) MPSP:2913 psi (Assuming all gas) Min ID:2.313” @ 8724 MD Tie In Log:NA Brief Well Summary: S-104 was historically a Kuparuk only injector, having injected over 17 mmbw and almost 8 bscf MI (66% HCPVWI and 18% HCPVMI respectively) in the Kuparuk before being temporarily isolated to establish injection up-hole in the Schrader Bluff in mid-2020. Now that injection has been established, we propose to restore injection to the Kuparuk, and proceed with co-mingled injection. Kuparuk injection in S-104 will continue to support offset producers S-122 and S-103, both of which have shown strong production responses to S-104 injection in the past. Optimal throughput volumes for the Kuparuk are 30% HCPV MI and at least 100% HCPV water, leaving substantial remaining value to restoring injection. Notes Regarding Wellbore Condition: 8/13/2020 Set PX Plug @ 8724' MD 7/24/2020 AOGCC MIT-IA passed to 2516 psi 7/18/2020 Set upper patch (ME) @ 6481' MD. MIT-IA passed to 2401 psi. 7/17/2020 Set XX plug @ 6508' MD in lower straddle. CMIT-TxIA passed to 2396 psi. Pulled XX plug from 6508' MD. 7/13/2020 Lower packer (ME) for patch set @ 6505' MD. 7/12/2020 Pull XX plug from Nip Reducer @ 8424' MD. 4/29/2020 Pulled patch from 6461' - 6495' MD Objective: Restore Kuparuk injection by installing a MCX valve in the Kuparuk zone. Procedure: SL 1. Pull PX plug and prong at 8724’ MD to restore injection to Kuparuk. 2. Set 2-7/8’’ MCX valve at 8724’ MD with largest orifice size available. (Talk with Justin H or Brad E. MCX will be used to not allow cross flow into the Schrader when SI) 3. RDMO Commingled water injection involving Polaris Oil Pool wells authorized by CO 484A. - DSR-1/22/21 Well: S-104 PTD:200-196 API: 50-029-22988-00 WBS Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:200-196 6.50-029-22988-00-00 PRUDHOE BAY, AURORA OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9196 8724 6692 6853, 7061, 7201, 8679 8724 4988, 5169, 5291, 6647 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 29 - 109 29 - 109 1530 520 Surface 3708 9-5/8" 28 - 3736 28 - 2863 5750 3090 Intermediate Production 9159.72 7" 26 - 9186 26 - 7149 7240 5410 Perforation Depth: Measured depth: 6920 - 8840 feet True vertical depth:5046 - 6807 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 24 - 8736 24 - 6703 Packers and SSSV (type, measured and 6853 / 7061, 7201, 8679 4988 / 5169, 5291, 6647 True vertical depth) 4-1/2" Baker S-3 / 4-1/2" Baker SABL-3 Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1441 2255 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen brian.glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5277 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured7159 Sundry Number or N/A if C.O. Exempt: 319-324 & 320-066 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Patch Tubing Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028257 & 028258 PBU S-104 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:59 am, Aug 25, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.25 10:43:00 - 08'00' Stan Golis RBDMS HEW 8/27/2020 SFD 8/31/2020DSR-8/27/2020MGR02SEP2020 ACTIVITY DATE SUMMARY 1/18/2020 ***WELL S/I ON ARRIVAL*** RIG UP HES SLICKLINE UNIT 046. ***CONTINUE ON 1/19/20 WSR*** 1/19/2020 ***JOB CONTINUED FROM 1/18/20 WSR*** RAN 3.70" G RING TO PATCH @ 6,463' ELM. 8 FAILED ATTEMPTS TO PULL PATCH FROM 6448' SLM ***CONT JOB ON 1/20/20 WSR*** 1/20/2020 ***WELL S/I ON ARRIVAL***(patch tubing/ liner) SWCP 4517 RIG UP ***CONTINUE JOB ON 21-JAN-2020*** 1/20/2020 ***CONT JOB FROM 1/19/20 WSR*** (Patch / Tubing Liner) JARRED ON BAKER 45 KB PATCH @ 6463' MD FOR 5 HOURS. ***JOB SUSPENDED / DSO NOTIFIED*** 1/21/2020 ***JOB CONTINUED FROM 20-JAN-2020*** (patch tubing/ liner) JARRED ON 45KB PATCH @ 6,463' MD FOR 7 1/2 HOURS W/ .160" WIRE ***CONTINUE JOB ON 22-JAN-2020*** 1/22/2020 ***JOB CONTINUED FROM 21-JAN-2020*** (patch tubing/ liner) JARRED ON 45 KB PATCH @ 6,463' MD FOR 10 HOURS W/ .160" WIRE ***CONTINUE JOB ON 23-JAN-2020*** 1/23/2020 T/I/O=200/300/0 Temp=SI Assist SLine (ATCH TUBING / LINER). Pumped 59 bbls 180* Crude in the TBG to assist SLB to pull patch from TBG. SLB incontrol of well upon departure. FWHP's = 1010/1058/-4 1/23/2020 ***JOB CONTINUED FROM 22-JAN-2020*** (patch tubing/ liner) PULLED 45 KB PATCH FROM 6,463' MD, PATCH HUNG UP @ 124' SLM ATTEMPTED TO JAR PATCH BACK DOWNHOLE EQUALIZED & PULLED 2 7/8" XX PLUG FROM 7,035' MD LRS PUMPED HOT CRUDE DOWN TUBING TO HELP FREE PATCH PULLED PATCH TO SURFACE (missing 2 elements) ***CONTINUE JOB ON 24-JAN-2020*** 1/24/2020 ***JOB CONTINUED FROM 23-JAN-2020*** (patch tubing/ liner) MADE 2 RUNS W/ 4-1/2" BRUSH, 3.50" WIRE GRAB TO NIPPLE REDUCER @7035' MD (recovered 2 pieces of rubber element) PULLED NIPPLE REDUCER FROM 7,035' MD RAN 4-1/2" BRUSH, 3.50" WIRE GRAB TO STICKY BOTTOM @8815' SLM (no recovery) RAN 10'x 2.74" DUMMY WHIP STOCK TO STICKY BOOTOM @ 8817' SLM (sample bailer full of shmoo) RAN READ 40 ARM CALIPER FROM 8800' SLM TO SURFACE ***WELL S/I ON DEPARTURE*** (job incomplete) 1/25/2020 ***JOB CONTINUED FROM 24-JAN-2020***(patch tubing/ liner) SWCP 4517 RIG UP ***CONTINUE JOB ON 26-JAN-22020*** 1/26/2020 T/I/O=500/500/0 Temp=SI. (A/SL Patch TBG/LNR). Stand-by for slickline to run plug. Begin weather stand-by. *** JOB CONTINUED ON 27-JAN-2020*** Daily Report of Well Operations PBU S-104 Daily Report of Well Operations PBU S-104 1/26/2020 ***JOB CONTINUED FROM 25-JAN-2020*** (patch tubing/ liner) RAN 40.25' x 3.77" PATCH DRIFT TO 6,600' SLM (all clear) SET 4 1/2" x 2 7/8" NIPPLE REDUCER IN XN NIPPLE @ 8,724' MD (sucker rod connection broke above spangs on the way out of hole) FISHED SPANGS AND X LINE FROM TOP OF NIPPLE REDUCER @ 8,724' MD WEATHER STANDBY DUE TO WIND CHILL AND TEMPS CLOSE TO -40 ***CONTINUE JOB ON 27-JAN-2020*** 1/30/2020 T/I/O=500/500/0 Temp=SI (A/SL PATCH TUBING/LINER) CMIT-TxIA to 2602 psi *****PASS***** Target psi = 2500 Max Applied psi = 2750 Pumped 5.7 bbls DSL down Tbg for CMIT-TxIA. Took Tbg/IA to 2702/2763 psi. Tbg/IA lost 76/79 psi in the 1st 15 mins and 24/25 psi in the 2nd 15 mins for a total loss of 100/104 psi in 30 min test. Bled Tbg/IA to 415/445 and got back ~4 bbls. SLine in control of well per LRS departure. FWHP's=400/422/-13 **hung tags on master and IA ***AFE sign already on well 1/30/2020 ***COME OFF WEATHER HOLD, JOB CONTINUED FROM 26-JAN-2020*** (patch tubing/ liner) CONFIRM GOOD SET OF 4-1/2''x2-7/8'' NIPPLE REDUCER AT 8,724' MD W/ 4- 1/2'' CHECK SET. SET 2-7/8'' XX PLUG IN NIPPLE REDUCER AT 8,724' MD. LRS PERFORMS PASSING CMIT TxIA TO 2500 PSI. ***WELL TURNED OVER TO DSO*** 2/21/2020 ***WELL SHUT IN ON ARRIVAL. CONTACT DSO.*** SPOT IN EQUIPMENT, LTT, PREP FOR PATCH SETTING ***JOB CONTINUES ON 22-FEB-19*** 2/22/2020 ***CONTINUED FROM 21-FEB-20*** SET 4 1/2" NS ONE TRIP STRADDLE, TOP ELEMENT SET AT 6465', BOTTOM ELEMENT SET AT 6495.15', TOP OF PATCH @ 6461, OAL = 38.78', MIN ID = 2.81" X-nipple, CCL STOP @ 6454.5', CCL TO UPPER ELEMENT 10.5' CORRELATED TO PDS LEAK DETECT LOG DATED 28-JUL-2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 3/8/2020 Road unit to location and spot. ***WSR Continued on 03-09-2020*** 3/9/2020 ***WSR Continued from 03-08-2020*** T/I/O=185/225/0 Temp=SI MIT- IA and TBG (PATCH TUBING / LINER) Pumped 7 bbls total of DSL in attempt to MIT-IA. TBG and IA tracked. Pumped at 1 BPM rate, TBG tracked instantly pound for pound up to max applied pressure. See log for details. AFE sign on well ***FLUID PACKED WELL*** Caution tag hung on IA and WV. Valve positions=SV,WV,SSV closed MV open CV's OTG FWHP=65/95/0 Daily Report of Well Operations PBU S-104 4/28/2020 ***WELL S/I ON ARRIVAL*** (profile modification) SET NS LTTP IN NS ONE-TRIP STRADDLE AT 6436' SLM. MIT-T TO 2500 PSI (pass) PULL NS LTTP FROM 6436' SLM SET 3-1/2'' XX PLUG IN X NIPPLE IN NS ONE-TRIP STRADDLE AT 6497' MD. LRS MIT-T TO 2500 PSI (pass) EQUALIZED & PULLED 3-1/2" XX-PLUG AT 6,497' MD LRS ATTEMPTED MIT-IA, TBG & IA TRACKED INSTANTLY ***CONT ON 4/29/20 WSR*** 4/28/2020 T/I/O= 61/92/6 ( LRS Unit 76 Assist Slick line ) SL set plug in patch. MIT-T to 2508 psi **PASSED** (Max 2750 psi, Target 2500 psi). MIT-IA Failed. Pumped 3.1 bbls diesel down TBG to reach test pressure for MIT- T. 1st 15 min TBG lost 153 psi, 2nd 15 min TBG lost 42 psi for a total loss of 195 psi in 30 min. Bled TBGP, bled back ~ 2.3 bbls. Pumped 3.4 bbls diesel down IA for MIT- IA. 1st 15 min IA lost 42 psi, 2nd 15 min IA lost 14 psi for a total loss of 56 psi in 30 min. SL pulled plug out of patch. Attempted to pressure up IA with 2.5 bbls diesel for MIT-IA and TBG pressure tracked up with IA. ...Continue on 4/29/20... 4/29/2020 ***CONT FROM 4/28/20 WSR*** (profile modification) PULLED 4-1/2" NS STRADDLE PKR FROM 6,461' MD (intact) SET 4-1/2" WHIDDON CATCHER ON NIP REDUCER AT 8,724' MD PULLED BK-DGLV FROM STA#3 AT 6,920' MD ***CONT ON 4/30/20 WSR*** 4/29/2020 ***Continued from 04/28/20*** (LRS unit 76 assist SL) - (PATCH, WFRV) SL pulled patch, set catcher. SL pulled station #3. ...Continue on 4/30/20... 4/30/2020 ...Continue from 4/29/20... LRS unit 76 assist SL (PATCH/WFRV) Pumped 2.2 bbls diesel down TBG to help keep over balance during station #3 change out. Station #3 set. Performed SRT on station #3 with bbls 7 60/40 meth, results as follows: 1000 psi ~ 0.037 bpm, 1200 psi ~ 0.056 bpm, 1400 ~ 0.145 bpm, 1600 ~ 0.284 bpm. To confirm Retest Station #3 pumped 16 bbls 60/40, results: 1000 psi ~.057 bpm, 1200 psi ~.184 bpm, 1400 psi ~.252 bpm, 1600 psi ~.261bpm. Pumped 33 bbls 60/40 meth down TBG to assist with Station #2 c/o and SRT's. SRT on stations #2 and #3 as follows: 1000 psi ~ 0.121 bpm, 1200 psi ~ 0.283 bpm, 1400 psi ~ 0.65 bpm, 1600 psi ~ 0.668 bpm. ...Continued on 05/01/20... 4/30/2020 ***CONT FROM 4/29/20 WSR*** (profile mod) SET BK W/ EXTENDED BOTTOM-BAKER WFRV (5/32" orifice/no spacer/light spring/202 bwpd) IN STA#3 AT 6,920' MD PERFORM SRT ON STA #3 (see LRS log for details) SET BK W/ EXTENDED BOTTOM-BAKER WFRV (7/32" orifice/no spacer/light spring/377 bwpd) IN STA#2 AT 7117' MD PERFORM SRT ON STA #3 & #2 (see LRS log for details) ****CONT WSR ON 5-1-20**** Daily Report of Well Operations PBU S-104 5/1/2020 ****CONT WSR FROM 4-30-20****(patch) PULL BK-DGLV FROM STA #1(7266' MD) SET BK W/ EXTENDED BOTTOM-BAKER WFRV (5/32" orifice/no spacer/light spring/202 bwpd) IN STA#1. PULL 4-1/2" WCS FROM 8,700' SLM LRS PERFORM SRT ON STA#1,2,3 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 5/1/2020 ...Continue from 4/30/20... LRS unit 76 assist SL (PATCH / WFRV) Pumped 43 bbls 60/40down TBG for SRT on Stations #1, #2, #3 1000 psi ~ 0.170 bpm, 1200 psi ~ 0.417 bpm, 1400 psi ~ .839 bpm, 1600 psi ~ 0.879 bpm.. RDMO. Tags hung on IA, MV, and WV. AFE sign on MV ***FLUID PACKED ANNULUS***. SL in control of well upon LRS departure. FWHP=485/756/4 ***Job Complete*** 7/12/2020 **WELL S/I ON ARRIVAL, OPEN PERMIT W/ PAD OP** EQUALIZED & PULLED 2-7/8" XX-PLUG FROM NIP-REDUCER @ 8724' MD **JOB COMPLETE, PAD-OP TO BOI** 7/13/2020 ***WELL SHUT IN ON ARRIVAL*** (set lower patch section) SET LOWER PACKER OF NORTHERN SOLUTIONS 450-281 PATCH MID- ELEMENT AT 6,505'. TOP OF PATCH AT 6,481'. OAL = 29'. MIN ID = 2.81" (3- 1/2" X NIPPLE AT 6,508'). CORRELATED TO PDS LDL DATED 26-JUL-13. ***JOB COMPLETE. WELL SHUT IN ON DEPARTURE*** 7/17/2020 T/I/O= 262/91/vac Assist Slickline CMIT TxIA PASSED to 2500 psi (Patch) Load tbg with 10 bbls crude. SL set plug. Pump 7 bbls crude to test TxIA lost 88/85 psi 1st 15 min & 31/33 psi 2nd 15 min. Bled back 3 bbls FWHPs=515/600/vac 7/17/2020 **WELL S/I UPON ARRIVAL***(patch intergrity) SET 3 1/2 XX PLUG IN LOWER STRADDLE PATCH @ 6508'MD MITIA WITH LRS, PASSED MITIA EQUALIZE AND PULL 3 1/2 XX PLUG FROM 6508' MD ***JOB CONTINUED ON 7/18/20*** 7/18/2020 ***JOB CONTINUED FROM 6/17/2020*** (upper patch) RIH W/ 2.75 DPU, NS UPPER PACKER/PATCH (28'6'OAL, 4 1/2 G FISHNECK, O.D.3.778") Tagged lower section @ 6481'. SET UPPER PACKER @ 6455' MD mid element. LRS MITIA UPON DEPARTURE ***WELL LEFT S/I UPON DEPARTURE**** 7/18/2020 T/I/O=287/260/0 Assist Slickline MIT IA PASSED to 2500 psi (Patch) Pumped 1.8 bbls crude to test. IAP lost 127 psi 1st 15 min & 22 psi 2nd 15 min Bled back 1.8 bbls FWHPs=279/250/0 7/24/2020 T/I/O=310/0/40 Temp=140* AOGCC MIT-IA ( AOGCC MIT-IA) AOGCC MIT-IA to 2516 psi ***PASS*** Target psi=2500 Max Applied psi=2700 Pumped 2.7 bbls DSL down IA to take pressure to 2687 psi. IA lost 158 psi in 1st 15 mins and 13 psi in 2nd 15 mins for a total loss of 171 psi in 30 min test. Bled IA to 3 psi and got back ~2.6 bbls. Witnessed by WSS Conrad and State Rep Jones. FWHP's=307/8/45 IA,OA=OTG Tag hung on CV Daily Report of Well Operations PBU S-104 8/11/2020 T/I/O = 520/1580/390. Temp = 140°. Bleed IAP (UIC). On PWI. IA FL @ surface. Bled IAP to BT from 1580 psi to 20 psi in 10 min (Fluid, 1.3 bbls). OAP drecreased 160 psi. Monitored for 30 min. IAP increased 60 psi, OAP increased 10 psi. Final WHPs = 520/80/240. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:20 8/13/2020 ***WELL INJECTING ON ARRIVAL*** BRUSHED 2.313" X-NIPPLE IN NIPPLE REDUCER @ 8,724' MD. SET 2.313" PX PLUG BODY & PRONG @ 8,724' MD. ***WELL LEFT S/I ON DEPARTURE*** I►iVx MelM340111 WV TO: Jim Regg I P.I. Supervisor C / FROnI: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-104 PRUDHOE BAY UN AURO S-104 Src: Inspector Reviewed By: P.I. Supry ,n Comm Well Name PRUDHOE BAY UN AURO S-104 API Well Number 50-029-22988-00-00 Inspector Name: Jeff Jones Permit Number: 200-196-0 Inspection Date: 7/24/2020 Insp Num: mitJJ200727110415 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j s-104Type Inj w `TVD 4988 - Tubing 310 314 311 311 - — - - PTD 2001960 (Type Test SPT Test psi 1500 IA 1 2687 - 2529 2516 BBL Pumped: 2.7 BBL Returned: 2.6 OA 42 61 - 67 67 - IntervalOTHER P/F P ✓ Notes' MIT-lA post atch repair per sundry 319-324. 1 well inspected, no exceptions noted. Wednesday, July 29, 2020 Page I of 1 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Alex Youngmun Kuparuk and Schrader Bluff PE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S-104 Permit to Drill Number: 200-196 Sundry Number: 320-066 Dear Mr. Youngmun: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www. o og cc.o laska. gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely DATED this\ © day of February, 2020. -ABDMS FEB 1 12n STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® 1. Type of Request. Abandon ❑ Plug Perforations 0 ' Fracture Stimulate ❑ Repair Well ❑ arpe2aons s�mwu..,u Stimulate ❑ Pull Tubing 11 CIN e 0 Suspend ❑ Perforate ❑ Other �.I�rem m Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Open New Pool (Polars) 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exlorato 13 Development ❑ p ry Service 0. 5. Permit to Drill Number. 200-196 - 3 Address : P.O. Box 196612 Anchorage, AK 6. API Number. 50-029-22988-00-00' 99519-6612 Stratigrephic ❑ U 7. If perforating. if U Ge. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes [I No ® pBU 5-104 ' Will planned perforations require a spacing exception? 4r� 9, Property Designation(Lease Number): 10. Field/Pools: Pv10J`15 61)`?" PRUDHOE BAV, A OIL 1 ADL 028257 8 028258 PRESENT WELL CONDITION SUMMARY 11 Total Depth MD (1h: Total Depth TVD(ft): Effective Depth MD'. Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9196 7159 8724 6692 8724 None MD TVD Buret Collapse Casing Length Size SINClural Conductor 80 20" 29-109 29-109 1530 520 Surface 3707 9-5/8" 28-3736 28-2863 5750 3090 Intermediate 26-9`186 26-7149 7240 5410 Production 9160 7" Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD ( 6920 - 8840 5046-6807 4-1/2" 12.6# L-80 24 - 8736 24 Packers and SSSV Type: 4-1/2" Baker S-3 Hydro Set Packer Packers and SSSV MD (ft) and TVD (ft): 6853 / 4988 7061 / 5169, 7201 / 5291, 8679 / 6647 4-1/2" Baker SABL-3 Packer (3) 12. Attachments: Proposal Summary 21 Wellbore Schematic p 13. Well Class after proposed work: , 11 BOP Sketch ❑ Exploratory ❑ Stretigrephic ClDevelopment ❑ Service D Detailed Operations Program 14. Estimated Date for Commencing Operations. February 12, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ® GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: GINJ ❑ Op Shutdown ❑ Abandoned El Commission Representative: - 17. 1 hereby certify that the foregoing is We and the procedure approved herein will not Contact Name: Youngmun, Alex 17. be deviated from without prior written approval. Contact Email: younakL@BP.com Authorized Name: Youngmun, Alex Contact Phone: +1 907 564 4864 Authorized Title: Kuparuk & Schrader Bluff PE Authorized Signature: g / 1'ex 1w'n J — Dale: �LIf I Z li COMMISSION USE ONLY Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Plug Integrity Other: �BDMS' FEB Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1(J. --4I007 APPROVED BYTHE ` COMMISSIONER COMMISSION Date: Approved by: Form 10-003 Revised 04/2017 ORIGINAL Approved appliabon is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate AOGCC February 5, 2020 5-104 (PTD #200-196) was completed in 2001 with the ability to inject in both the Schrader Bluff Pool) and Kuparuk (Aurora Pool). On completion, the well only injected in the Aurora Pool. There currently is an approved sundry (#319-324) for setting a patch and testing injectivity in the Polaris Pool. A new multi- lateral producer, 5-202, was drilled near 5-104's Schrader Bluff injection location resulting in value for establishing Schrader Bluff injection into 5-104. The revised plan is to plug the Aurora Pool and inject into the Polaris Pool for several months to obtain baseline Polaris injectivity trends prior to commingling the Polaris and Aurora Pools. A separate request will be submitted to commingle the Polaris and Aurora pools E� at a later date. 1. Pull XX plug set in nipple reducer at 7,035' MD. - Complete 2. Pull Patch set at 6,663'-6,501' MD. - Complete 3. Pull nipple reducer set at 7,305' MD. -Complete 4.40 -arm caliper from TD to surface. - Complete 5. Set nipple reducer at 8,724' MD. Set XN plug at 8,724' MD. - Complete 6. Pressure test IA to verify integrity post patch and pressure testing TBG to ensure plug set to 2,500 psi. - Complete 7. Set one -trip big bore patch 2.83" ID. Set element -to -element from 6,465' to 6,495' MD. 8. Pull dummy valve from 6,920' MD and set WFRV 9. Perform step -rate injectivity to check valve performance. 10, Pull dummy valve 7,170' MD and set WFRV 11. Perform step -rate injectivity to check valve performance. 12, Pull dummy valve from 7,266' MD and set WFRV 13, Perform step -rate injectivity to check valve performance Alex Youngmun Alex.Younemun @bp.com +1907 564-4864 TREE= 41/16" CIW VC.LHEAD= FMC ACTUATOR= LEO OKB. ELEV = 64.50' BF. ELEV = 382Z KOP= 75V Max Angle = 57" @ 3230' Datum MD= 879T DatumTVD= 67WSS I9-5/8" CSG, 40#, L-80 BTC, D = 8.835" 1 " MARKER JT (20r) W/RA TAGJ—+ $499' f 412" TBG JT #40 W/ RA TAG 6681' Minimum ID = 2.313" @ 8724' 2-7/80" NIPPLE REDUCER PH2FORATION SUMMARY Fill LOG: SWS PLATFORM IXPRESS GRRES ON 01/27/01 ANGLEATTOPF1UiF: 8' @ 8790' Note: Refer to Production DB for historical pert data SIZE SPF 9NTERVAL Opn/Sqzj SHOT SOZ 4-5/8" 6 6920-6980 C 02104/01 29 4-5/8" 6 7018-7050 C 02/04/01 2 45/8" 6 7070-7094 C 02/04/01 BK 4-5/8' 6 7114-7124 C 02!04/01 30 4-5/8" 6 7162-7182 C 02/04/01 4-5/8" 6 7216-7266 C 02/04/01 45/8' 6 7280-7302 C 02A4(01 4518" 6 7325-7346 C 02/W01 2-718" 6 8790 -8810 O 11/05/14 3-38" 6 8810-8840 O 0326/01 33/8' 6 8816-8836 O 05/01/03 4112" TBG, 12 6#, L-80 NSCT, .0152 bof . D = 3 958" PBTD 1 9100' CSG, 26#, L-80, BTC -M, D = 6.276" 9196' SAFETY NOTES: H12S READINGS AVERAGE 125 ppm S104 WHEN ON MI" WELL REQUIRESA SSSVWHEN ON MI 41/2" HES X NP, D = 3.813" GAS LFT MANDRELS MD JTVDJ MVI TYPE I VLV LATCH POI 4839 3495 54 1 KBG2-TIL I DMY I BK 1 0 6731 4883 31 KBG2-TIL DMY BK 0 6842' —j 4-12' HES X NP, D = 3.813" 6863' 7" X 412" BKR S3 PKR ID = 3.875" PRODUCTION MANDRELS ST MD TVD DEV TYPE I VLV ILATCH PORT DATE 3 6920 5046 29 KBG2-T/L ONTt' BK 0 02107/01 2 7117 5218 30 KBG2-TIL Ok4Y BK 0 02/07/01 1 7266 5347 30 KBG2-TIL DMY BK 0 02/07/01 7035' 4-12" BKR CMU SLD SLV, OTIS PROF., 1)- 17- = I7' X 4-1/2" BKR SABL-3 PKR D= 3.875' 41/2" BKR CMU SLD SLV, OTIS PROF, D= 3.812- 7201' —j7" X 4-12" BKR SABL-3 PKR, [)=3.875- 7333' =3.875"7333' 412' BKR CMU SLD SLV, OTIS PROF, D 8679' -17- X 4-12' BKR SABL3 PKR, D= 8703--]--14-112- HES X NP. D=3.813' I arz4- l—I 111Z no nry rvr. v=o.c�o 8724 1-14-12"X 2-7/8" NIP REDUCER, ID = 2 8724 --12-718" XX PLUG (010020) 8736' 412' WLEG, ID =4.00' ELMD Tr NOT LOGGED DATE REV BY COMMENTS DATE I REV BY COMMENTS 02109MI N9ES ORIGINAL COMPLETION 11/12/14 DJS/PJC PULL XX PLUG 12103114 GC/PJC ADPERFS 11/05114 08102/16 EZ/JMD EDITED OLD PERFS S/B CLOSED 0621/19 EPD/JMD SET 2-7/8"XX PLUG 06/07/19 0210320 JMG/JMD PULLED PATCHIRESET NP RED & PLUG AURORA UNIT WELL: S-104 PERMIT NO: '2001960 API No: 50-029-22988-00 TI 2N, R12E, 4646' NSL & 449, BP Exploration (Alaska) TREE= 4-1116' OW 1AflLFFAD= FMC ACTUATOR= -- LEO 0103.9.EV =_ - 64.50 BF. HJ=V = KOP.-__. 38.27 750 Nuc Angle = Datum tip- . 57'@ 3230 8797 Datum ND= 6700SS ETY NOTE: H2S READINGS AVERAGE 125 ppm S-104 F!;F '�'ON MI WELL REQUIRES A SSSV WHEN ON M I PROPOSED CSG, 4D#, L-80 BTC, D = 8.835'3--f 736' J-- 17' MARKER JT (20') WI RA TAG f4-112- TBG JT #40 VW RA TAG 6881' Minimum ID = 2.313" @ 8724' 2-7/8" NIPPLE REDUCER F67FORATDN Su%WRY Pill LOG: SWS PLATF0FW IXFRPSS GRIRES CN 01127101 A NGLE AT TOP F$2F: 8' @ 8799 Note: Refer to Production DB for historical pert data SIZE SPF KIEEWAL OpnSgz SHOT SOZ 4-518' 6 6920-6980 O 02104/01 0 4-5/8' 6 7018-7050 O 02/04101 KBG2-TIL 4-5/8' 6 7070-7094 O 02/04/01 7266 4-5/6' 6 7114-7124 O 02/04/01 0 4-518' 6 7162-7182 O 02/04/01 4-518' 6 7216-7266 O 02/04101 4-518' 6 7280 - 7302 O 02104/01 4-518' 6 7325-7 02/04/01 T 2-7/8' 6 8790 - 8810 C 11105/14 3-318' 6 C 0326101 3-3/8' 6 "08MO C 05101103 4-112' TBG, 12.6#, L-8 _D152 buf . D = 3.958' pBTD 9100' ;;W276- I 9188' >-'HESXP GAS LFT 48831 31 1 KBG2-TIL I DMV I BK10 12'HES X NP, D=3.615 X 4-12' BKR S-3 FlUk D = mnnrlYlN MANDRFLS FqTI MD I TVD I DEVI TYPE I VLV ILATCH I PORT DATE 3 5046 29 KBG2-TILWFRV BK 0 02/07101 2 16920 7117 5216 30 KBG2-TIL WFRV BK I 0 02/07/01 1 7266 5347 30 KBG2-TIL WFRV BK 0 02107101 CMU SLD SLV X 4-112' BKR 12' BKR CMU X 8703' H4-12' HES X NP. D = 3913' 8724' H4-12' PES XN NP, D= 3.1 8724 412'X2-718'NIP REDUCE 8724 XX PLUG(01/300 I 8736' �2-718' n 4-12'WLEG,ID=400' I ELMD TT NOT LOGGED DATE REV 8V COMMENTS DATE REV BV COMMENTS ?021M910! NIIES ORIGINALCOWLETION DJSIPJC PULL XXPLUG GC/PJC ADPERFS 11/05114 EZ/JMO EDITED OLD PERFS -SIB CLOSED EPD/JMDSET 2-718' XX PLUG 7119 2tFEEI JMGIJM PULLED PATCHIRESET NP RED 8 PLUG S PROF., D = 3.612' D = 3.875' B PROF, D = 3.812' D = 3.875' IS PROF, D = 3.812' D = 3.875 - ID = 75'ID= 2 313' (012620) AURORA UNIT WELL S-104 PERMIT No: 81001960 API N0: 50-029-22988-00 T12K R12E, 4646 NSL B 449' BP Exploration (Alaska) Z09-&-ir Date: 11/18/2019 3 1999db 9 Transmittal Number: 93714 BPXA WELL DATA TRANSMITTAL Enclosed is a disc with the requested core photos and analysis. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendallgbp com. APLWellNo WI Permit Well Nm Core Photos Core Analysis, Description, etc 50029229780000 2001620 PRUDHOE BAY UN BORE Z-101 50029229880000 2001960 PRUDHOE BAY UN AURO 5-104 50029229950000 —2010590 2002080 PRUDHOE BAY UNIT Z-39 50029230080000 PRUDHOE BAY UN BORE V-100 50029231610000 1 2031030 PRUDHOE BAY UN BORE V-111 50029233880000 2080530 PRUDHOE BAY UN ORIN L-205 L-205PB1* *Plug -back analysis located in BP archive database. Please sign and email a copy of this transmittal to. GANCPDCAbp365 onmicrosoft com Thank you, Mer .Merion Xendaff SIM Specialist BP Exploration Alaska1900 E. Benson Blvd.lRoom: 716BIAnchorage, AK Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 JAN 3 0 2020 1 A®GCC 2:?0196 WELL LOG TRANSMITTAL # 3 1 1 8 1 To: Alaska Oil and Gas Conservation Comm. September 3, 2019 Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: S-104 Run Date: 6/7/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 S-104 Digital Data (LAS), Digital Log file RECEIVED 1 CD Rom 50-029-22988-00 SEP 10 2019 , %%''uVU PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: °nom ��c �<Ac FRS—A] Date: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Lea Duong Senior Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU S-104 Permit to Drill Number: 200-196 Sundry Number: 319-324 Dear Mr. Duong: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jessie L. Chmielowski Commissioner DATED this ' day of July, 2019. RBDMSL �"'1UL 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 E EN ED JUL vi ri/ 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Cha P re111 ❑ Alb Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other a a 0 Injectivity Testing 2. Operator Name: SP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 200.196 3. Address: P.O. Box 198612 Anchorage, AK 99519-8612 Stretigrephic Cl Service m 6. API Number: 60-029-22988.00-00 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned Perforations require a spacing exception? Yes ❑ No 0 PBU S-104 9. Property Designation (Lease Number): 10. FielNPools: ADL 028257 & 028258 PRUDHOE BAY, AURORA OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Tote) Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9196 7159 7035 5147 7035 None Casing Length Sin MD TVD Buret Collapse Structural Conductor 80 20" 29-109 29-109 1530 520 Surface 3707 9-5/8" 28-3736 28-2863 5750 3090 Intermediate Production 9160 7" 26-9186 26-7149 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6920- 6840 5046 - 6807 4-1/2" 12.8# L-80 L-80 24-8736 Packers and SSSV Type: 4-1/2" Baker S-3 Hydro Set Packer Packers and SSSV MD (ft) and TVD (ft)' 6853/4988 4-12" Baker SABL-3 Packers (3) 7061 / 5169, 7201 / 5291, 8679 / 6647 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed wont: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: 07/31/2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 r GSTOR ❑ SPLUG ❑ I Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Duong, Lea be deviated from without prior written approval. Contact Email: Lea.DuongQbp.com Authorized Name. Duong, Lea Contact Phone: +1907 564 4840 Authorized Title: Senior Petroleum Engineer Authorized Signature: Date: COMMISSION USE ONLY n Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L✓-, Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS 0611UL 1 81019 11 Spacing Exception Required? Yes ❑ No R"' Subsequent Form Required: AffI TT APPROVED BYTHE Approved by:� COMMISSIONER COMMISSION Date:( J ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from theda a of approval. Attachments in Duplicate i� n �IPvotg ,,-0 �I$ � 1% 10-403 Sundry Application for Well PBU S-104 PTD# 200-196 Expected Start Date: July 31, 2019 Current condition of well: WAG Injection Well, Not Operable, Offline: Water Injection Rate: 0 bw d Injection Pressure: 582 psi Shut-in Wellhead Pressure: 0 psi Reservoirpressure: 3583 psi Well objective(s): S-104 recently shut-in for integrity. A LDL was executed and found a leak just below the current patch. The plan is to take the opportunity to obtain injectivity in each zone of the Shrader formation while the patch is removed. After the diagnostic is completed, will reset the patch and return well back to operational status. Proposed program: 1. Pull XX plug set in nipple reducer at 7,035' MD. 2. Pull Patch set at 6,663'-6,501' MD. 3. Pull nipple reducer set at 7,305' MD. 4. 40 -arm caliper from TD to surface. 5. Set nipple reducer at 8,724' MD. Set XN plug at 8,724' MD. 6. Combo pressure test to ensure plug set to 2,500 psi. ***Do Not Pump Crude*** 7. Open Sleeve #1 (upper most) at 7,035' MD. RDMO 8. Tubing FL Shot. POI Well for 7-10 days. Facility to conduct Step Rate Test #1 9. Close Sliding Sleeve #1 at 7,035' MD. Combo Pressure Test to ensure Sleeve is closed. 10. Fullbore to assist SL. Combo Pressure test with diesel to 2500 psi. ***Do Not Pump Crude*** 11. Open Sliding Sleeve #2 at 7,175' MD. RDMO 12. Tubing FL Shot. POI Well for 7-10 days. Facility to conduct Step Rate Test #2 13. Close Sliding Sleeve #2 at 7,175' MD. Combo Pressure Test to ensure Sleeve is closed. 14. Fullbore to assist SL. Combo Pressure test with diesel to 2500 psi. ***Do Not Pump Crude*** 15. Open Sliding Sleeve #3 at 7,333' MD. RDMO 16. Tubing FL Shot. POI Well for 7-10 days. Facility to conduct Step Rate Test #3 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU S-104 PTD# 200-196 17. Close Sliding Sleeve #3 at 7,333' MD. Combo Pressure Test to to ensure Sleeve is closed. 18. Fullbore to assist SL. Combo Pressure test with diesel to 2500 psi. ***Do Not Pump Crude*** 19. Set one -trip big bore patch 2.83" ID. Set element -to -element from 6,465' to 6,495' MD. New drawings will come from vendor for exact set depths. If HAL log not available to tie-in, PDS leak point surrey 28 -Jul -2013 is sufficient. 20. Pressure test to verify operability - MIT -IA to 2,500 psi - If fails, contact APE to discuss. 21. MIT-TxIA to 2,500 psi 22. Pull plug set in nipple reducer at 8,724' MD BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU S-104 PTD# 200-196 Current Well Bore Schematic: ELLV = "My NOTE: ROS RE/(Oa105 AVERAGE 125 PPm S-104 W ON"I^WELL REOUWESASSSVW..ONMI DATE COM wM DATE REV BY COMABOS 0211401ONOIMLL COMPLETION /1/10114 Aa' P SET 45 NB PATCH O5QM AOBFS 11 R1WV'P PATC710fi1HCC1RRRn ON0111914 M101EFY SET2-7/O'PLLrdW ✓®(01/11114) 11/12114 DHPJC RLLXXRUG0924/14 SETBKRPATCH(0Y1QM) 12AY14 OT2 PJC AOEWS(1Vn14) 1110Y14RLL PATCH R.UCI NPf�CR OBA7J10 FZ/JMJ EDTEDODR3FS SIB CLOS®11/07/14SET MPFUM&IO( RUCNSSD 1/1860' SET2-71WXXILUG 7/10) BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 AURORA LM VALL 5-104 FS;M o: X101960 AMb: 500232298600 n2N R12E 4846 NEL a 4494 Nfl SP 9pbwlbn IAWka) Rixse, Melvin G (CED) From: Duong, Lea <Lea.Duong@bp.com> Sent: Tuesday, July 9, 2019 2:19 PM To: Rixse, Melvin G (CED) Subject: RE: PTD200-196, PBU S-104, Sundry Request 319-324 Injectivity Testing It will be produced water and maxed pressure is 2000 psi but for the Step rate test, it will be 1400 psi. We will not inject above 4300 bbls/day. I don't think the pressure will be our max limit, it will be our injection rate since the SB can take fluids readily. Thanks, Lea From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Tuesday, July 9, 2019 12:26 PM To: Duong, Lea <Lea.Duong@bp.com> Subject: PTD200-196, PBU S-104, Sundry Request 319-324 Injectivity Testing Lea, What will be your maximum injectivity test pressures for your step rate injectivity tests on the SB formation? What fluids will be used to check injectivity? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin.RixsePalaska.gov). I Slickline DrAtubing. WSLdiscreflontocalloutfullbore. Bailing maybe required. Pull Patch 2 Pull RMX body @ 6549' MD. Set PX Plug @ 6,549' MD 3 Fullbore Fullbore to assist SL Unit 4 Pressure test tubing to 2000 psi. IFfail, Record LLR. Communication into OA sand in well report. OA Sand face gauge is working. 5 Slickline Pull Px Plug @ 6,549' MD. Pull RMX Body and WFRV @ 6,626' MD. 6 Pull Flow Sleeve set @ 6,632' MD. krstall Dummy valve in Station #3 (6,632' MD). 7 Pull Plug at 6,804' MD. Fullboreto assist in B&F. 8 Fullbore Brush and Flush 60 bbls of 180 F of diesel and flush down tubing tail. 9 Slickline Reset plug @ 6,804' MD. 10 Pull Station#1 at 6,775' MD (Port Size 16, Light, 345 bwpd). 11 Replace Station #1 at 6,775' MD with port size 17, Light, 395 bwpd. 12 Fullbore Perform step -rate injecbvityat 1000, 1200, 1400, and 1600 psi to check valve performance. 13 Target injection of 0.48 bpm on 2% KCL water. • If Station #4 may be plugged, may see rate 0.27 b m. Also hole across the OA sand below the Acker."` 14 Slickline Reinstall RMX bodyand dummy prong @ 6,626' MD 15 Pull Station #4 @ 6,576' MD (Port Size 15, Light, 300 bwpd) `"'Once pulled, well may fall under a vacuum"` 16 Fullbore Perform open -pocket injectivity#1 at 200, 400, 600, and 800 psi. Hold each interval for 10 minutes. Maximum allowable rate is 3 bpm. Indicate (OBa Sand) in WSR. 17 ffrate is >2 bpm @ 1,000 psi, perform Red Dye Treatment. See Red Dye Steps in other tab. 18 Slickline Replace in kind (Port Size 15, Light, 300 bwpd) 19 Fullbore Perforn step -rete injectivity, at 1000, 1200, 1400, and 1600 psi to check valve performance. 20 Target injection of 0.21 bpm on 2% KCL water. -Target injection may be affected if tubing leak into the OA sand below the Production acker- 21 Slickline Pull dummyvalve from Station#5 (6,533' MD). Has extended packing. 22 Slickline Set new WFRV port size 11, Light, 160 bwpd 23 Fullbore Perfor i step -rate injectivltyat 1000, 1200, 1400, and 1600 psi to check valve performance. 24 Target injection rate of 0.32 bpm on 2% KCL water. 25 Slickline Pull dummy prong @ 6,626' MD 26 Fullbore Perform step -rate injectivity, at 1000, 1200, 1400, and 1600 psi to check valve performance. 27 Target injection rate of 0.59 bpm on 2% KCL water. 28 Slickline Pull dummy valve from Station #3 (6,632' MD). Set Flow Sleeve. 29 Install new live WFRV in nipple profile at 6,626' MD. Set port sin 19, Light, 500 bwpd 30 Fullbore Perform step -rate injectivityat 1000, 1200, 1400, and 1600 psi to check valve performance. 31 Target injection rate o10.66 bpm with 2% KCL water. "'Maybe off due to a leak below production Acker."' 32 '**Send valves to GL Engineer for teardown- 33 Eline Attemptto redress the 3 1/2" one trip patch pulled by SL if possible, if not will set a 3 112" two tnp WFC assembly with the Relay unit"` Set one or two Mp WFD 3 1/2" WidePak VO rated patch over 6,439' MD to 6,464' MD Reference Tie -In Log. HAL LDL 08/11/17 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Thursday, June 6, 2019 8:49 AM To: AK, GWO Well Integrity Engineer; AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL; Duong, Lea; Nottingham, Derek, Peru, Cale; Thompson, Ryan; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A, Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED); AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector S-104 (PTD #2001960) TxIA communication confirmed with failing MIT -IA All, Injector S-104 (PTD #2001960) was made under evaluation on 5/9/2019 for having anomalous inner annulus repressurization. On 5/10/2019 DHD performed a failing MIT -IA confirming TxIA communication and the well was shut in and freeze protected on 5/13/2019. Further diagnostics and repair have been delayed by the Kuparuk river bridge outage. The UE period is now expired and the well is reclassified as Not Operable. Plan Forward: 1. Slickline —Secure well, Leak detection log 2. Production Engineer— Evaluate for repair Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWOVell Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Thursday, May , 19 7:35 AM To: AK, OPS EOC Specialists ;ts@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellp ad <AKOPSGC2WelIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers op sprodcontrollersl@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWe W@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRES astWellsOptEngr@bp.com>; AK, RES GPB Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Thursday, May 9, 2019 7:35 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Duong, Lea; Nottingham, Derek; Peru, Cale; Thompson, Ryan; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras 1; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector S-104 (PTD #2001960) Anomalous inner annulus repressurization after bleed Attachments: S-104.pdf All, Injector S-104 (PTD #2001960) was identified as having anomalous inner annulus repressurization on 5/9/2019 during a routine UIC bleed. The repressurization indicates a potential failure of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Wellhead— PPPOT-T 2. DHD—MIT-IA 3. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 RECEIVED STATE OF ALASKA AIDA OIL AND GAS CONSERVATION COMMON DEC 1 8 2012 REPORT OF SUNDRY WELL OPERATIONS OGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L Brightwater Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. ShutdooJn ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ 200 -196 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service El 6. API Number: Anchorage, AK 99519 -6612 0.. 50- 029 - 22988 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028258 - S -104 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, AURORA OIL 11. Present Well Condition Summary: 1 Total Depth measured 9196 feet Plugs measured None feet true vertical 7158.95 feet r' Junk measured None feet Effective Depth measured 9100 feet Packer measured See Attachment feet true vertical 7064.16 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 28 - 108 " `• 1530 520 Surface 3708 9 -5/8" 40# L -80 28 - 3736 28 - 2862.97 5750 3090 Intermediate None None None None None None Production 9160 7" 26# N -80 26 - 9186 26 - 7149.08 7240 5410 Liner None None None None None None Perforation depth Measured depth See Attachment feet SCANNED MAR 11 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 - 8736 24 - 6703.8 Packers and SSSV (type, measured and true vertical depth) See Attachment • S•e Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 4003 980 Subsequent to operation: 3919 1000 14. Attachments: 15. Well Class after work: r. Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: , Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG o GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 E -mail Nita.Summerhays @bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Sig natu / ��jr :j7 - /p / /Jj _ _, -- -••••••• - Phone 564 -4035 Date 12/14/2012 e- :,,n,:° : ;_t., i .: L,;:szr— ; ,Z... a.zo.,- A , 2444_ Form 10-404 Revised 11/2011 Submit Original Only • • • Daily Report of Well Operations ADL0028258 ACTIVITYD TE ., SUMMARY Standby for Piggin job to be comp e e. :rig a er - eservoir weep I o• 11/7/2012 ***Continued on WSR 11 -08- 2012 * ** 11/8/2012 Standby for Piggin Job to be completed ( Brightwater Reservoir Sweep Mod) T/I /O = 1550/1000/220 ** *Job Continued from WSR 11 -08- 2012 * ** Temp =Not (Bfightwater Reservoir Sweep Mod) Move in, Rig up 11/9/2012 ** *Continued on WSR 11- 10- 2012 * ** T /I /0 = 1300/1000/220 ** *Continued WSRfrom 11 -09- 2012 * ** Temp =Hot ( Brghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 360 gal. EC9360A (Surfactant) Average of 15 gph for 24 hrs. Pumped a total of 360 gal. since start of project. Pumped 1517 gal. EC9398A ( Polymer) Average of 63.2 gph for 24 hrs. Pumped a total of 360 gal. since start of project. 11/10/2012 ** *Continued on WSR 11 -11- 2012 * ** T /I/O = 1350/1000/220 ** *Continued WSR from 11 -10- 2012 * ** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 352 gal. EC9360A (Surfactant) Average of 14.6 gph for 24 hrs. Pumped a total of 712 gal. since start of project. Pumped 1606 gal. EC9398A ( Polymer) Average of 66.9 gph for 24 hrs. Pumped a total of 3123 gal. since start of project. 11/11/2012 ** *Continued on WSR 11 -12- 2012 * ** T /I /0= 1400/460/100 Temp= SI Freeze protect Tbg & F/L ( Brightwater shut -down for pigging ). Pumped 10 bbls neat methanol down F/L to freeze protect. Pumped 50 bbls neat methanol down 11/12/2012 Tbg to freeze protect. FWHP's= 1380/460/100 SV,WV= SI SSV,MV= 0 IA & 0A= OTG. 171/0 = 1350/1040/220 * * *ContinuedWSR from 11 -11- 2012 * ** Temp =Hot ( Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 99 gal. EC9360A (Surfactant) Average of 12.3 gph for 24 hrs. Pumped a total of 811 gal. since start of project. Pumped 512 gal. EC9398A ( Polymer) Average of 68.2 gph for 24 hrs. Pumped a total of 3635 gal. since start of project. 11/12/2012 ** *Continued on WSR 11 -13- 2012 * ** T1110 = 1347/960/18G ** *Continued WSR from 11 -12- 2012 * ** Temp =Hot (Bnghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 138.5 gal. EC9360A (Surfactant) Average of 10.65 gph for 13 hrs. Pumped a total of 949.5 gal. since start of project. Pumped 747.5 gal. EC9398A ( Polymer) Average of 57.5 gph for 13 hrs. Pumped a total of 4382.5 gal. since start of project. 11/13/2012 ** *Continued on WSR 11 -14- 2012 * ** T /1 /0 = 1317/960/180 ** *Continued WSR from 11- 132012 * ** Temp =Hot ( Brghtwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 348 gal. EC9360A (Surfactant) Average of 14.5 gph for 24 hrs. Pumped a total of 1297.5 gal. since start of project. Pumped 1662 gal. EC9398A ( Polymer) Average of 69.25 gph for 24 hrs. Pumped a total of 6044.5 gal. since start of project 11/14/2012 ** *Continued on WSR 11/15/2012 * ** • • • T /I /O = 1304 /980 /200 ** *Continued WSR from 11- 14- 2012 Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 341 gal. EC9360A (Surfactant) Average of 14.2 gph for 24 hrs. Pumped a total of 1639 gal. since start of project. Pumped 1532 gal. EC9398A ( Polymer) Average of 63.83 gph for 24 hrs. Pumped a total of 7576 gal. since start of project 11/15/2012 """Continued on WSR 11/16/2012 * ** 171 /0 = 1346/930/190 ** *Continued WSR from 11- 15- 2012* ** l emp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 150 gal. EC9360A (Surfactant) Average of 15 gph for 10 hrs. Pumped a total of 1789 gal. since start of project. Pumped 732 gal. EC9398A ( Polymer) Average of 73.2 gph for 10 hrs. Pumped a total of 8308 gal. since start of project 11/16/2012 FWHP= 1339/1060/220 ** *Well injecting @ 6000 BWPD on departure * ** FLUIDS PUMPED BBLS 60 METH 1689.5 EC -9360 SURFACTANT 6134.5 EC -9398A POLYMER 7884 TOTAL .. • • Packers and SSV's Attachment ADL0028258 SW Name Type MD TVD Depscription S -104 PACKER 6853 4923.42 4 -1/2" Baker SABL -3 Packer S -104 PACKER 7061 5104.66 4 -1/2" Baker SABL -3 Packer S -104 PACKER 7201 5226.07 4 -1/2" Baker SABL -3 Packer S -104 PACKER 8679 6582.86 4 -1/2" Baker SABL -3 Packer Casing / Tubing Attachment ADLOO28258 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 28 - 108 28 - 108 1530 520 PRODUCTION 9160 7" 26# N -80 26 - 9186 26 - 7149.08 7240 5410 SLEEVE 5 1/2" Baker CMU Sliding Slee 7035 - 7040 5146.55 - 5150.9 SLEEVE 5 1/2" Baker CMU Sliding Slee 7175 - 7180 5268.05 - 5272.38 SLEEVE 5 1/2" Baker CMU Sliding Slee 7333 - 7338 5404.88 - 5409.2 SURFACE 3708 9 -5/8" 40# L -80 28 - 3736 28 - 2862.97 5750 3090 • • TRH= 414/6' OW • S NOTES: H2S READINGS AVERAGE 125 ppm ACIUATORR= LEO S-1 04 W1 ON MI. WELL REQUIRES A SSSV WHEN ON KB. EIEI! = 64.50' 'BF. ELEV = 38.22' KOP 750' @ 3230 { 1008 H 9 5!8' TAM PORT COLLAR Max Angle = 57° Datum MD = 8797' 1 2403' H 4-1/2" HES X NP, D= 3.813' 1 Datum ND = 6700' SS 19 -5/8" CSG, 40#, L-80, D = 8.835" H 3736' GAS LFT MANDRELS Minimum ID = 3.725" @ 8724' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 -112" HES XN NIPPLE 5 4839 3495 54 KBG-2 -7'/L OMY BK 0 05/10/02 4 6731 4883 31 )G-2-17L DMY BK _ 0 05/10/02 r MARKER JT (20') W/ RA TAG 6488' = PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 14-1/2" TBG JT #40 W/ RA TAG H 6681' 3 6920 5046 29 KBG-2 7'/L DMY BK 0 02/07/01 2 7117 5218 30 KBG -2 -T/L DMY BK 0 02/07/01 1 7266 5347 30 KBG -2 -T7L DMY BK 0 02/07/01 I 6842' H 4-1/2" F4 :S X NF; D = 3.813" 1 ∎7'1 6853' H r X 4-1/2" BKR SABL -3 PKR, D= 3.875' 1 PERFORATOR SUMMAFi1' RE= LOG: SWS R.ATFORM EXPRESS GRIR6 ON 01/27/01 1 1 • 7035 H 4-1/2" BKR CMU SLIDING SLV, OTIS PROF., D = 3.812' j ANGLE AT TOP PE: 29° @ 6920' ' ET 7061' H 7" X 4-1/2" BKR SABL -3 PKR, D = 3.875" 1 Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sgz /DATE m 1 7175' H 41/2' BKR CM IN U SLIDING SLV, OTIS PROF, D = 3.812" 1 4-5/8" 6 6920 - 6980 0 02/04/01 45/8' 6 7018 - 7050 0 02/04/01 7201' 7" X 4-1/2" BKR SABL -3 PKR D = 3.875" 1 4-5/8" 6 7070 - 7094 0 02/04/01 45/8" 6 7114 - 7124 0 02/04/01 I 7333' H 4-1/2" BKR CNA.I SLIDING SLV, OTIS PROF, D = 3.812" 1 I 4-5/8" 6 7162 - 7182 0 02/04/01 4-5/8" 6 7216 - 7266 0 02/04/01 4-5/8" 6 7280 - 7302 0 02/04/01 45/8" 6 7325 - 7346 O 02/04/01 3-318' 6 8810 -8840 O 03/26/01 867W H 7" X 4-1/2" BKR SABL -3 PKR, D = 3.875' 1 3-3/8' 6 8816 - 8836 0 05/01/03 8703' H 4-1/2" HES X NP, D = 3.813" 1 1 8724' H 4-1/2' HES XN NP, D= 3.725" 1 14-1/2" TBG, 12.6#, L -80, .0152 bpf , D = 3.958" H 8736" 8736' H 4-1/2" WLEG, D = 4.0(T I ' I H ELMO TT NOT LOGGED I PBTD 9100' AVAWAVI t t j tt 10010 t j j j t j j 1 7" CSG, 26#, L - 80, M 13= 6276' H 9188' 411 4 1 t t 1 t DATE FEV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 02/09/01 ORIGINAL CONF.ETION 05/01/03 BJMKK ADPERFS WE L: S-104 02/10/01 CSsrnoski CORRECTIONS 10/22/05 RAC/PJC ACTUATOR CORRECTION PERMIT No: * 2001960 06/11/01 G} Uh PERF CORRECTION 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE AR No: 50- 029 - 22988 -00 09/03/01 KSB/tlh NPPLE D CORRECTION 01/19/12 TMTY,M) ADDED H2S SAFETY NOTE SEC 35, T12N, R12E, 4646' NSL & 4494' IAEL 04/09/02 RWCWTP C:ORFECTIONS 12/12/12 GCIJMD GLV PO CORRECTION (05/10/02) 04/09/03 DRS/TP TVD/ND CORRECTIONS 1 BP Exploration (Alaska) • MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~i~7 7'Z{.r~10 FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-104 PRUDHOE BAY iJN AURO 5-104 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN AURO S-] 04 API Well Number: 50-029-22988-00-00 Insp Num: mitCS100714065620 Permit Number: 200-196-0 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 7/13/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-IOa - Type Inj. w TVD 4988 ~ IA ~ 820 4000 ~ 3960 3960 P.T.D 2001960 ~ TypeTest SPT Test psi Isoo OA s7o 970 9~0 9~0 Interval aYRTST p~F P Tubing 2490 2490 2490 2490 Notes: pre-test pressures were observed for 30+ minutes and found stable. ~r~ ~~ d-~esk I~Cb~ Wednesday, July 14, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.reggti~alaska.gov; phoebe.brooks@a~ska_gov; tom.maurxler~a~ska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska}, Inc. FIELD /UNIT !PAD: Prudhoe Bay /PBU ! S-Pad DATE: 07!13110 OPERATOR REP: Trffany Quy AOGCC REP: Chuck Scheve Packer Pretest initial 15 Min. 30 Min. Well S-104 T In'. W TVD 4,988' Tu ' 2,490 2,490 2,490 2,490 Interval 4 P.T.D. 2001960 T test P Test 1500 820 4,0110 3,960 3,964 P/F P Notes: 4year AOGCC MITIA to 4000 psi OA 570 370 970 970 Well T in". TVD Tubi Interval P.T.D. T test Test ~ Casi P/F Notes: OA Well T In'_ TVD T Interval P.T.D. T Pest Test - P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test PiF Notes: OA Well T In'. TVD T Interval P.T.D. T test Test ~ Casi P/F Notes: OA TYPE INJ Codes TYPE TEST Codes r!~ ~.: e~ ~y fed ~ ,~,, ?-? (~ I ,~ ~ ~ f~ ~ ~ {r,` INTERVAL Codes ~-~~3 D =Drilling Waste M =Annulus Monitorvig I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Internal Radioactive Tracer Survey V =Required by Variance N = Not injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11127/07 MIT PBU S-104 07-13-10.x1s ~ • bp BP Exploration (Alaska) Inc. ~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 * ~~~~ Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of welis from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~~~~~ ,~u~. t{ .?DC~~ Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Spad ~ Date 6/25/2009 Well Name PTD # Initial top af cement Vol. of cement um ed Final top of cement Cement rop oti date Corrosion inhibitor Conosion inhibi[od sealant date ft bbls ft na al S-07B 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 0.25 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26I2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-088 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31I2009 S-11B 1990530 025 NA 025 NA 1.7 5/27/2009 S72A 1851930 025 NA 025 NA 1.7 6/1/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-79 1861160 0.75 NA 0.75 NA 22 5/79/2009 S-20A 2010450 0.25 NA ~ 025 NA 1.3 5/19/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 0.25 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.s 5/37I2009 S-29A1t 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 5-38 1921270 0.25 NA 025 NA 102 5/27/2009 5-47 1960240 1.5 NA 1.5 NA 71.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5728/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-701 2001150 125 NA 125 NA 17.9 5/29/2009 S-102L7 2037560 125 NA 125 NA 11.1 5/31/2009 5-103 2001680 7.5 NA 1.5 NA 11.9 5/18/2009 5-104 ~ 2001960 1.75 NA 1J5 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA /625 NA 174.3 6/2/2009 5-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-i08 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-109 2022450 2 NA 2 NA 27.3 5/30/2009 S-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-1 ~ t 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.7 5/18/2009 5-114A 2021980 1.25 NA 125 NA 102 5/30/2009 Si15 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 1.5 NA 1.5 NA 13.6 5l28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-7~8 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-127 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-722 2050810 3 NA 3 NA 21.3 5/29/2009 5-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA 71.9 5/26/2009 5-125 2070830 225 NA 2.25 NA 20.a 5/28/2009 5-126 20710970 125 NA 725 NA 15.3 6/1/2009 5-200 1972390 1.25 NA 125 NA 14.5 5/28I2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 &1/2009 5-216 2007970 4.75 NA 4.75 NA 57 5/29/2009 5-277 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA s9.5 6/2/2009 S-SOa 0 NA 0 NA O.eS 5/28/2009 _ _ ~,,~ STATE OF ALASKA ~~~ -D~ N01t 2 6 2007 ALASKA OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIOIV~+ska Oil & Gas Cons. Commission 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other HT WATER Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension ~ TREATMENT - Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 200-1960 - 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-22988-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.5 KB PBU S-104 - 8. Property Designation: 10. Field/Pool(s): ADLO-028258 ~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 9196 ~ feet Plugs (measured) None true vertical 7158.95 - feet Junk (measured) None Effective Depth measured 9100 feet ~-~.ir~~ NO V 9 ZVU! 6~ true vertical 7064 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 28 - 108 28 - 108 1530 520 Surface 3708 9-5/8" 40# L-80 28 - 3736 28 - 2862.97 5750 3090 Production 9160 7" 26# N-80 26 - 9186 26 - 7149.08 7240 5410 Perforation depth: Measured depth: 6920 - 6980 7018 - 7050 7070 - 7094 7114 - 7124 7162 - 7182 7216 - 7266 7280 - 7302 7325 - 7346 8810 - 8840 8816 -8836 True Vertical depth: 5046.25 - 5098.62 5131.75 - 5159.6 5176.98 - 5197.83 5215.18 - 5223.86 5256.78 - 5274.11 5304 - 5347 5359 - 5378 5398 - 5416 6777 - 6807 6783 - 6803 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 8736 0 0 - Packers and SSSV (type and measured depth) 4-1 /2" Baker S-3 Perm Packer 6853 4-1/2" Baker SABL-3 Packer 7061 4-1/2" Baker SABL-3 Packer 7201 4-1/2" Baker SABL-3 Packer 8679 12. Stimulation or cement squeeze summary: Intervals treated (measured): `~ : . r~ ~. ~i(~~f 2Q~7 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 7644 1340 1608 Subsequent to operation: 3178 940 1347 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ ' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NfA if C.O. Exempt: N/A Contact Danielle Ohms Gary Preble 564-4944 Printed Name Danielle O Title Sr. Petroleum Engineer Signature ~.~.~-" Phone 564-5759 Date 11/21/2007 Form 10-404 Revised 04/2006 ~*~.f Submit Original Only l~ S-104 • Date Time Water bw d Pressure si EC9378 inches EC9378 al Chemical um d al EC9360 inches EC9360 al Chemical um d al COMMENTS 10/13/2007 3:30 3800 1700 37.3 2464 62.5 4664 Start 'ob 10/14/2007 6:00 8700 1700 25.8 1421 1043 55.5 4056 608 9378 pump broke at 7:30. Shut down all chemical injection. Major pump failure. Pum not repairable. 10/18/2007 17:15 7600 1700 25.8 1421 0 53.0 3832 224 Substituted triplex to pump 9360. Remaining operational pump head in skid used for 9378. 10/18/2007 21:15 7600 1700 19.0 922 499 42.0 2877 955 Tri lex um down. Shut down all chemical injection. 10/19/2007 9:30 3100 1500 19.0 922 0 41.5 2834 43 Restart triplex and chemical injection. Triplex pumping at 200 gph at lowest settin .Cannot finish 'ob with this setup. 10/19/2007 19:30 3100 1500 4.0 91 831 21.0 1062 1772 9378 IMO em ty. Shut down 9378. 10/19/2007 23:30 3100 1500 0.0 0 91 3.0 61 1001 9360 IMO empt .Shut down 9360. End 'ob and flush lines. Total Pum ed 2464 4603 Remainder 0 0 :, S-104 Remainder Total Shipped EC9378 from E-23 and 3-04 2460 2460 Remainder ~ ~ ~ Total Shipped EC9360 from E-23 and 3-04 4660 4660 NOTE: No full IMO were used on this job. One IMO of 9378 was sent to the slope but it was not used. The full IMO was sent back to Fairbanks. 04/25/07 Schlum~erger NO. 4223 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ')IC-- ÐCò - ¡G¡fo Company: Alaska Oil & Gas Cons COffiffi Artn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Well Job# Log Descríption Date BL Color CD L-213 . 11649950 MEMORY IPROF 03/17/07 1 W-210 11626075 USIT 03/06/07 1 S-104 10563057 INJECTION PROFILE 05/03/03 1 L-218 10913045 CEMENT/PERF EVALUATION 09/04105 1 L-218 10913045 MDT 09/04/05 1 S-111PB1 40011960 OH EDIT MWD/LWD OS/24/05 2 1 S-111PB2 40011960 OH EDIT MWD/LWD 06/06105 2 1 L-202 40012011 OH EDIT MWD/LWD 06117/05 2 1 L-202L1 40012011 OH EDIT MWDILWD 06/24/05 2 1 L-202L2 40012011 OH EDIT MWDILWD 06/29/05 2 1 L-202L3 40012011 OH EDIT MWDILWD 07/05/05 2 1 S-122 40012137 OH EDIT MWD/LWD 08/17/05 2 1 S-122PB1 40012137 OH EDIT MWD/LWD 08109/05 2 1 S-122PB2 40012137 OH EDIT MWD/LWD 08/14/05 2 1 S-122PB3 40012137 OH EDIT MWD/LWD 08/15/05 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Ine Petrotechnical Data Center lR2~1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED APR 3 0 Z001 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Date Delivered: Received by: . Alaska 0i18¡ C'an~o Commissloo Anchorage ,~MAY () 1 2.{){)7 J'j ~'~~ ~- (<q" e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test i/... I I l<...e?(1' 7 Zç'iJ~; Email to:Winton_Auber1@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudoe Bay / PBU / S-Pad 07/15/06 Jack Winslow Packer Depth Pretest Initial 15Min. 30 Min. We1l1S-34 I Type Inj. W TVD I 9,848' Tubing 760 430 400 400 Interval 4 P.T.D.11921360 I Type test I P Test psi! 2462 Casing 640 2,500 2,400 2,360 PIFI P Notes: MIT-IA for Reg. Compo OA 280 430 400 370 Chuck Scheve declined to witness We1l1S-104 I Type Inj. W I TVD I 6,853' Tubing 3.100 3,100 3.100 3.100 Interval I 4 P.T.D.12001960 I Type test P Test psi 1713.25 Casing 630 1.800 1.780 1.770 PIFI P Notes: MIT-IA for Reg. Compo OA 0 30 30 30 Chuck Scheve declined to witness Weill I Type Inj.1 I TVD I I Tubingl I Interval p.T.D.1 I Type test I I Test psi I Casing I PIFI Notes: OAI I Weill I Type Inj. I TVD I Tubing Interval P.T.D.I I Type test I Test psil I Casing PIF Notes: I OA Weill Type (nj.1 I TVD Tubingl Interval P.T.D. I Type test I I Test psil Casing I I P/F Notes: OAI TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlVey A = Temperature Anomaly SUlVey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT PBU 5-34,104 07-15-06.xls I ,\L..,L,t::.l V t:.lJ _ STATE OF ALASKA _ . .. . AlA~ Oil AND GAS CONSERVATION COM~ION MAR 1 7 ¡UOb REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D Other 0 AMd._IIâ*:> WAG Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver 0 Time Extension D 12/10/2003 Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development CI Exploratory 200-1960 3. Address: P.O. Box 196612 Stratigraphic CI Service W: 6. API Number: Anchorage, AK 99519-6612 50-029-22988-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.5 KB 8. Property Designation: ADL-028258 11. Present Well Condition Summary: Total Depth measured 9196 true vertical 7158.95 Effective Depth measured 9100 true vertical 7064.16 Casing Conductor Surface Production Length 80 3708 9160 Size 20" 94# H-40 9-5/8" 40# L-80 7" 26# L-80 Perforation depth: Measured depth: 6920 - 6980 7216 - 7266 True Vertical depth: 5046.25 - 5098.62 5303.57 - 5346.87 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations S-104 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 28 - 108 28 - 3736 26 - 9186 TVD 28 - 108 28 - 2862.97 26 - 7149.08 Burst 1530 5750 7240 Collapse 520 3090 5410 7018 - 7050 7280 - 7302 5131.75 - 5159.6 5358.99 - 5378.04 7070 - 7094 7325 - 7346 5176.98 - 5197.83 5397.95 - 5416.13 7114-7124 8810 - 8840 5215.18 - 5223.86 6777.12 - 6806.84 7162-7182 8816 - 8836 5256.78 - 5274.11 6783.07 - 6802.88 4-1/2" 12.6# L-80 24 - 8736 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker SABL-3 Packer 4-1/2" Baker SABL-3 Packer 4-1/2" Baker SABL-3 Packer 6853 7061 7201 8679 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 3225 800 7700 440 15. Well Class after proposed work: Exploratory CI Development 16. Well Status after proposed work: Oil CI Gas WAG W Tubing pressure 1393 3397 ServiceM WDSPL [J 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sharmaine Vestal ~_ Slg",~ ~ ORIG Contact Sharmaine Vestal Form 10-404 Revised 04/2004 Title Data Mgmt Engr Date 3/14/2006 Submit Original Only ~-:,.. ~~...'._~ ',,*-,- ,. " ,'" "',, ' "" ...... '~ ;', , >\ ~~. MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2001960 MD 9196 - TVD DATA SUBMITTAL COMPLIANCE REPORT 8~7~2003 Well Name/No. PRUDHOE BAY UN AURO S-104 Operator BP EXPLORATION (ALASKA) INC 7159~ Completion Dat 2/9/2001 _ Completion Statu IWINJ Current Status 1WINJ APl No. 50-029.22988-00-00 UIC Y REQUIRED INFORMATION Mud Log N._9o Sample N._g_o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name Log Log Scale Media Interval Run No Start Stop Te ..~Temperature Ver LIS Verification P_.Er.e~Press u re ' - Directional Survey Directional Survey MWD Directional Survey MWD Directional Survey NEU/Den 2/5 Array 2/5 ~'~pole Sonic 5 ~ 5 'T:~XlAITIDSIIFMIIRFT 1 5 2 5 2/5 -G'MR/FMI I~[J;m~ n ic &.P~SsTvD BS BS 1 8574 8900 3630 9103 1 159 9188 1 8574 8900 FINAL 3630 9103 FINAL FINAL 5400 9098 FINAL FINAL FINAL FINAL 3735 9150 FINAL 3735 9150 FINAL 3735 9196 FINAL 5450 9100 FINAL 3735 9196 FINAL FINAL 5480 9100 FINAL 3745 9100 FINAL 4500 9090 FINAL 3735 9150 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Case 5/14/2002 Open 2/23/2001 Open 2/7/2002 ~7 Case 5/14/2002 OH 2/23/2001 ch 31112001 CH 3/2/2001 ch 3/1/2001 ch 3/1/2001 ch 3/1/2001 OH 2/23/2001 OH 2/23/2001 OH 2/23/2001 OH 2/23/2001 OH 2/23/2001 OH 2/23/2001 CH 3/2/2001 CH 3/2/2001 OH 2/23/2001 OH 2/23/2001 SBHP Survey 3630-9103 SBHP Survey 3630-9103 Digital Data Directional Survey Paper Copy 5400-9098 Color Print Directional Survey Digital Data Directional Survey Paper Copy Directional Survey Digital Data 3735-9150 BL, Sepia 3735-9150 BL, Sepia 3735-9196 BL, Sepia 5450-9100 BL, Sepia 3735-9196 BL, Sepia Color Print 5480-9100 Color Print 3745-9100 Color Print 4500-9090 Color Print 3735-9150 BL, Sepia Permit to Drill MD 9196 2001960 DATA SUBMITTAL COMPLIANCE REPORT 8/712003 Well Name/No. PRUDHOE BAY UN AURO S-104 Operator BP EXPLORATION (ALASKA) INC TVD 7159 Completion Dat 2/9/2001 Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22988-00-00 UIC Y Directional Survey FINAL ch 3/1/2001 Directional Survey Digital GYRO Data Directional Survey FINAL ch 3/1/2001 Directional Survey Paper GYRO Copy Cn See Notes 1 203 9196 Case 2/28/2003 '1-'r~50 Digital Well Logging Data Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments Core Chips 8771 8937 ADDITIONAL INFORMATION Well Cored? N Chips Received? '~)/N Daily History Received? ~_~ Formation Tops ~ N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X ADD PERFS Puli tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 633' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 1867' FNL, 5120' FEL, Sec. 26, T12N, R12E, UM At effective depth 1709' FNL, 684' FEL, Sec. 27, T12N, R12E, UM At total depth 1712' FNL, 705' FEL, Sec. 27, T12N, R12E, UM 5. Type of Well: Development _ Exploratory__ Stratigraphic_ Service_X ~sp~ 618931, 598085~ ~sp~ 618235, 5984885) ~sp~ 617389, 5985030) (asp's 617368, 5985026) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-104 9. Permitnumber/approvalnumber 200-196 10. APInumber 50-029-22988-00 11. Field / Pool Prudhoe Bay_Fie_!d / Aurora Pool 12. Present well condition summary Total depth: measured true vertical 9196 feet Plugs (measured) 7159 feet h(bCEJVFD TD Tagged @ 9060 (04/2372003~.~ JUN ! (~ 2003 Alaska 0il & Gas Cons. C0r~r~issien A~chorage Effective depth: measured 9160 feet Junk (measured) true vertical 7025 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 108' 20" 260 sx AS (Approx) 136' 136' Surface 3718' 9-5/8" 585 sx AS Lite III, 355 sx 3736' 2863' Class 'G' Production 9160' 7" 270 sx AS Lite III, 243 9186' 7149' Class 'G' Perforation depth: measured Open Perfs 6920'-6980', 7018'-7050', 7070'-7094', 7114'-7124', 7162'-7182', 7216'-7168', 7280'-7302', 7325'-7346', 8816'-8836', 8810'-8840' true vertical Open Perfs 5046'-5099', 5132'-5160', 5177'-5198', 5218'-5224', 5257'-5274', 5304'-5347', 5359'-5378', 5398'-5416', 6783'-6803', 6777'-6807' rubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 8679' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 8736' MD. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker 'SABL-3' Packers @ 6853', 7061', 7201' & 8679' MD. 4-1/2" 'X' Nipple @ 2403' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 04/30/2003 Subsequent to operation 05/05/2003 OiI-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 2588 4739 Casing Pressure Tubing Pressure 1798 1713 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas _ Suspended _ Service Water Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~ _~ ,~t~~~,~,~ Title: Technical Assistant . .: .:,,~,~.;~.,.~,~:~ ~ .,.... ,. ,,.,., ~. . DeWayne R. Schnd?r Form 10-404 Rev 06/15/88 · ORIGINAL Date MAY 06, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE S-104 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04~23~2003 IPROF: DRIFT/TAG 05/01/2003 PERFORATING: PERFORATING 05/03/2003 IPROF: INJECTION PROFILE 05/05/2003 TESTEVENT---INJECTION PRESSURE, PSI: 1,713 PSI TYPE: PW VOLUME: 4,739 BWPD. EVENT SUMMARY O4/23/O3 <<< WELL ON WATER INJECTION UPON ARRIVAL >>> DRIFTED W/3 3/8" DUMMY GUN 10' LONG, TT LOC,SB. UNABLE TO LOC. TT. -- TAGGED BOTTOM @ 9060' SLM. (TARGET = 8850'+) (BAILER EMPTY). ( NOTE: HAD - 900 # PICK UP WEIGHT @ 9000'). <<< TURNED WELL OVER PAD OPERATOR FOR INJECTION >>> O5/O 1/O3 PERFORATE - INTERVAL = 8816-8836 FT MD. TIED INTO SWS USIT LOG DATED 2-FEB-2001 WITH GUN GR. GUN = 3 3/8" HSD, 3406 POWERJET HMX CHARGES @ 3 SPF WITH PURE CHARGES. INTERVAL WILL BE SHOT TWICE = 6 SPF. GUNS AREA EACH 30 FT LONG WITH 20 FT IN THE MIDDLE LOADED WITH 3406'S AND TOP AND BOTTOM LOADED WITH PURE CHARGES. FOR BOTH RIH'S, TOOL = HEAD/AH66/PGGT-D/AH63/AH10-1/SAFE HEAD-ESlC/GUN = 45 FT X 3.375" OD. ****WELL LEFT SHUT IN - REQUESTED PAD OPERATOR PLACE WELL ON FULL INJECTION**** DID NOT TAG TD. 05/03/03 INJECTION PROFILE -TOOL = HEAD/AH38/SWIVEL/3 WEIGHTS/PBMS/PILS/PFCS = 37.2 FT X 2.125" MAX OD. PFCS CONFIGURED WITH MEDIUM ARMS, ROLLERS AND 2.5" SPINNER AS REQUESTED BY CLIENT. WELL ON INJECTION UPON ARRIVAL AT 2100 PSI - SHUT IN WELL FOR RIH TO BRING DOWN PRESSURE FOR STEP RATE TEST. NOTE WHEN ARRIVED, WELL READ 2100 PSI AT ABOUT 5600 BWPD. BUT WHEN LOGGED MAX RATE @ 10900 BWPD, WHP READ ONLY 1800 PSI. LOGGED STANDARD IPROF, THEN LOGGED BASELINE PASS FROM 9040 FT TO 6800 FT AGAINST INJECTION AT 10900 BWPD. SHUT IN WELL AND LOGGED 1 AND 2 HOUR WARMBACK PASSES. IT APPEARS THAT ALL INJECTION IS ENTERING THE PERFS AT 8010- 8040 FT MD. EVIDENCE OF A CHANNEL DOWNWARD FROM THESE PERFS WAS NOT FOUND. <<< PAD OPERATOR INFORMED - WELL READY TO POI >>> O5/O5/O3 TESTEVENT---INJECTION PRESSURE, PSI: 1,713 PSI TYPE: PW VOLUME: 4,739 BWPD. Page I S-104 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Fluids Pumped BBLS 1 DIESEL FOR PRESSURE TEST. 6 DIESEL 7 TOTAL ADD PERFS 05/01/2003 THE FOLLOWING INTERVAL WAS PERFORATED USING 3-3/8" HSD 3406 POWER JET, HM×, 3 SPF PURE SYSTEM (DOUBLE SHOT - SO IT IS PERFORATED 6 SPF). 8816' - 8836' Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SCHMOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X 4. Location of well at surface 633' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 1867' FNL, 5120' FEL, Sec. 26, T12N, R12E, UM At effective depth 1710' FNL, 690' FEL, Sec. 27, T12N, R12E, UM At total depth 1712' FNL, 705' FEL, Sec. 27, T12N, R12E, UM (asp°s 618931, 59808% (asp's 618235, 5984885) (asp's 617383, 5985029) (asp's 617368, 5985026) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-104 9. Permit number / approval number 200-196 10. APl number 50-029-22988-00 11. Field / Pool Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface 9196 feet Plugs (measured) 7159 feet Production 9100 feet Junk (measured) 7064 feet Length Size Cemented Measured Depth True Vertical Depth 108' 20" 260 sx AS (Approx) 136' 136' 3718' 9-5/8" 585 sx AS Lite III, 355 sx 3736' 2863' Class 'G' 9160' 7" 270 sx AS Lite III, 243 9186' 7149' Class 'G' Perforation depth: measured Open Perfs 6920'-6980', 7018'-7050', 7070'-7094', 7114'-7124', 7162'-7182', 7216'-7168', 7280'-7302', 7325'-7346', 8810'-8840' true vertical Open Perfs 5046'-5099', 5132'-5160', 5177'-5198', 5218'-5224', 5257'-5274', 5304'-5347', 5359'-5378', 5398'-5416', 6777'-6807' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 8679' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 8736' MD. Packers & SSSV (type&measured depth) 7" x 4-1/2" Baker 'SABL-3' Packers @ 6853', 7061', 7201' & 4-1/2" 'X' Nipple @ 2403' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) MAY 0 Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or I niectlo---'~ OiI-Bbl Gas-Mcr Water-Bbl C~,~tre Tubing Pressure Prior to well operation 04/18/2003 4997 1782 Subsequent to operation 04/21/2003 4612 1689 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil_ Gas__ Suspended_ Service Water Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~/~*~'~P~__~,~~~._~/ Title: Technical Assistant DeWayne R. Schnorr REtDI $ NAY Form 10-404 Rev 06/15/88 · ORiGinAL Date APRIL 23, 2003 Prepared by DeWayne R. Schnorr 564-5174. SUBMIT IN DUPLICATE q~'~"" S-104 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/07/2003 INJECTION CONVERSION: AC-FLUID LEVEL; AC-MONITOR 04/20/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 04/21/2003 TESTEVENT --- INJECTION PRESSURE, PSI: 1,689 TYPE: PW VOLUME: 4612 BWPD. EVENT SUMMARY 03/07/03 T/I/O=580/430/VAC FL FOR STATIC (10:00 AM). TBG FL AT SURFACE. 04/20/03 PUMPED SCHMOO-B-GONE TREATMENT. 5 BBLS NEAT METHANOL, 110 BBLS SBG/FRESHWATER, 3 BBLS NEAT METHANOL. 04/21/03 TESTEVENT --- INJECTION PRESSURE, PSI: 1,689 TYPE: PW VOLUME: 4,612 BWPD Fluids Pumped BBLS 8 NEAT METHANOL 110 SBG / FRESHWATER 118 TOTAL Page 1 I I .C) WELL LOG TRANSMITTAL To: State of Alaska February 25, 2003 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs' S-11M AURORA, AK-MM-10014 S-104 AURORA: Digital Log Images: I CD Rom PLEP~SE ACKNOWLEDGE RECEIPT BY 'sIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED FEt 2. 8 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Conversion to H20 Injection Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 633' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 1867' FNL, 5120' FEL, Sec. 26, T12N, R12E, UM At effective depth 1710' FNL, 690' FEL, Sec. 27, T12N, R12E, UM At total depth 1712' FNL, 705' FEL, Sec. 27, T12N, R12E, UM 5. Type of Well: Development m Exploratory__ Stratigraphic__ Service__X ~sp~ 618931, 5980850) ~sp~ 618235, 5984885) ~sp~ 617383, 5985029) (asp's 617368, 5985026) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-104 9. Permit number / approval number 200-196 / 302-147 10. APl number 50-029-22988-00 11. Field / Pool Prudhoe Bay Field/Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 108' Surface 3718' Production 9160' 9196 feet Plugs (measured) 7159 feet 9100 feet Junk (measured) 7064 feet Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS (Approx) 136' 136' 9-5/8" 585 sx AS Lite III, 355 sx 3736' 2863' Class 'G' 7" 270 sx AS Lite III, 243 9186' 7149' Class 'G' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 6920'-6980', 7018'-7050', 7070'-7094', 7114'-7124', 7162'-7182', 7216'-7168', 7280'-7302', 7325'-7346', 8810'-8840' true vertical Open Perfs 5046'-5099', 5132'-5160', 5177'-5198', 5218'-5224', 5257'-5274', 5304'-5347', 5359'-5378', 5398'-5416', 6777'-6807' 4-1/2", 12.6#, L-80, TBG @ 8679' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 8736' MD. 7" x 4-1/2" Baker 'SABL-3' Packers @ 6853', 7061', 7201' ~~E i V'E D 4-1/2" 'X' Nipple @ 2403' MD. 13. Stimulation or cement squeeze summary OCT 0 4 2002 Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 0il& Gas ns. C0mmtssi0 14. Representative Daily Average Production or Injection Dat~i[lc~lora~]e OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 06/14/2002 1982 1983 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil_ Gas_ Suspended_ Service Water Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. D~~.~~/)~ Title: Technical Assistant Form 10-404 Rev 06/15/88 · Date September 19. 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE S-104 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/08/2002 ANNCOMM 05/09/2002 ANNCOMM 06/06/2002 WATER INJECTION STARTED 06/13/2002 ANNCOMM EVENT SUMMARY 05/08/02 T/I/O = 1800/460/280 Temp = 126. MIT- IA to 3000 psi PASSED. (Pre AOGCC -- Inj Conversion). IA FL @ 260' (14 bbls). Pressured IA to 3000 psi with 9 bbls of 50/50 Methanol, Started 30 min test, IA lost 180 psi in 15 min. Re-pressured IA to 3000 psi, IA lost 0 psi in 30 min. Bled IA to 30C ,~r-; ~;~1 ~AIIII')I,-, I I OF~I"~/'~/")O/~ 05/09/02 T/I/O = 1850/400/280. Temp = 126. Monitor WHP's. (Post MIT- IA). 06/06/02 06/13/O2 WATER INJECTION STARTED. THIS WELL WAS DRILLED AS A PRE- PRODUCED WATER INJECTION WELL, T/I/O = 2000/550/620 MIT-IA PASSED to 2000 psi (AOGCC Chuck Scheve) MIRU LRS and pumped 1.7 bbls MEOH down IA to pressure up to 2020 psi, IA lost 20 psi in first 15 minutes and 0 psi in second 15 minutes. For a total loss of 20 psi during 30 minute test. Final pressures; 2000/480/620. Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL 10.7 50/50 METHANOL WATER 10.7 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _~X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 633' FNL, 785' FWL, Sec. 35, T12N, R12E, UM At top of productive interval 1865' FNL, 5120' FEL, Sec. 26, T12N, R12E, UM At effective depth 1710' FNL, 690' FEL, Sec. 27, T12N, R12E, UM At total depth 1712' FNL, 705' FEL, Sec. 27, T12N, R12E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service__ (asp's 618931, 5980850) (asp's 618235,5984885) (asp's 617383, 5985029) (asp's 617368,5985026) 6. Datum elevation (DF or KB feet) RKB 64.5 feet 7. Unit or Property name AURORA UNIT 8. Well number S-104 9. Permit number / approval number 200-196 10. APl number 50-029-22988-00 11. Field/Pool 'pV'u.~ ~ r,~ ~ AURORA ~ ~ if 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 108' Surface 3718' Production 9160' 9196 feet Plugs (measured) 7064 feet 9100 feet Junk (measured) 7159 feet Size Cemented Measured Depth True vertical Depth 20" 260 sx AS (Approx) 136' 136' 9-5/8" 585 sx AS Lite III, 3736' 2863' 355 sx Class 'G' 270 sx AS Lite III, 243 7" 9186' 7149' Class 'G' Perforation depth: Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) measured Open to Injection: 8810' - 8840' Behind Closed Sliding Sleeves: 6920'- 6980', 7018' - 7050', 7070' - 7094', 7114' - 7124', 7162'- 7182', 7216' - 7266', 7280' - 7302', 7325' - 7346' true vertical Open to Injection: 6777.1' - 6806.8' Behind Closed Sliding Sleeves: 5046.3' - 5098.6', 5131.8' - 5159.6', 5177' - 5197.8', 5215.2' 5215.2'- 5223.9', 5256.8'- 5274.1', 5303.6'- 5346.9', 5359'- 5378', 5398'- 5416.1' 4.5", 12.6 #, L-80, M-BTC at 8736' MD ~'"':. 4- 7" X 4-1/2" BKR SABL-3 Packers at 6853', 7061', 7201 ', 8679' MD , 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation August 20, 2002 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _ Gas _ Service WATER INJECTION Suspended__ 17. I hereby certify~a..t the foregging is true and correct to the best of my knowledge. ! Signed (,. I~.~'~.t0/,/~,,L~ Title: ., FOR COMMISSION USE ONLY Date~----~~' i,.~' -.-- (.,~,., Prepared by Garry Catron 564-4657 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test__ Subsequent form required 10- ("/07 Original S~gned By' Approved by order of the Commission Cammy Oechsli Taylor' Commissioner Form 10-403 Rev 06/15/88 · Approval no,~,~ Z "~ ~ -~-~ Dat.e ~2~¢~7 ........ /~ /- SUBMIT IN TRIPLICATE PERFORATING PROCEDURE Well: S-104 APl #: 50-029-22988-00 Date: ....................... ..8../..1...4.../..0...2. ........................ Prod E n g r ...J.!..m.....Y...o...u..n...g. .................... CC or AFC: AULWPS104 Detail Code: Var 4.0 0~/04J01 Office Ph: 564-5754 Home Ph: 248-0133 Cell/Pager: ........................... ,~.~,.0.'..~.0..0...7. ........................... 9335-070-770 II .2S Level: <.10.pp.m; Description:. D..R. Lr.G.../....C..O.....M...P...L..E....T..!.O....N.../.....P,.E....R..F.. ................................................................................................................................................................................................................................................................ WBL Entries IOR Type Work Desciption 1 O0 0 FP (MeOH) & stackout tb9 w/GL, treetop twin to S-105 for flowback 100 E Perforate 14' underbalanced Well Obiectives and LoCl,clin,(] Notes: New perforations require short-term flow back for cleanup which will also benefit existing perfs. 300psi dP has been eliminated by prior flowbacks for solids cleanup->10% II increase translates to lOObopd response Attachment: Reference log with proposed parrs annotated, 5"/100' scale Reference Log Tie in Log Log: PEX GR USIT Date: 1/27/2001 Company: SWS ~chlum Depths (from-to) ......... ,~,,,,8,,5,,,o. ................ ..8.,,,.,8..5..~ ...... 8,868' 8,874' . ......... 8..,.8.?. ............... ~.:..8...4....4..'. ............... ~:.~.!.~'. ....... Gas Jetting Expected? Add 0 to the tie-in log to be on depth with the reference log. Depths (from-to) Feet SPF Orient. ..... 8. ;,8,5,.,,0,'. ....... - ....... .,8..,..,8,,5.,.,8.,', ............. ,~'. .............. 6, ....... 8,.~.~8.'. ....... - ....... .~,.~..7....4.' .............. ..6.'. .............. 6.. ................................... 8,844' 30' 6 Phasing No At what Depth? feet Zone Ad/Re/Iperf ...... ..c,.,2,. ....................... !,,.p..e.~ .................. ...... ..C....2.. ....................... !..p...e..~ .................. ...... ..C...3.. .................... ..R..~..p...e..~ ............... N/A Requested Gun Size: .......... ,.3,;,.3,,,/,8. .......... Charge: ............. ,p. j,,3,,.4,,,0,,.6,. ............ Desired Penetration: >20" Entry Hole Diam: >0.3" Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check w~ Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie in to Jewelry @ 8690 MD Tie in using: Minimum ID: '.iii!:i'ii',i~ii~ii!ii:i:i',! in Min ID Type: Tail Depth: 8690 ft MD Casing Size: Est Res. Pres. @ Last Tag: >8900 ft MD on 10/21/2001 MULTIPLE X-NIPPLES @ 'MD ....... ~,,.~,.0,,0., ...... MD is ................ .3,,,0.,,0,.,0., psi Well: S-104 Date: General Comments: Perforation Summary APl #: 50-029-22988-00 Prod Engr: PBTD Summary Dist Town: ............................................... IAnch Prod Engr I P.D. Center Depths Zone Aperf/Reperf Referenced to BHCS - . Gun Dia. Orient. SPF Phasing Balance O/B/U O/B/U O/B/U O/B/U O/B/U ~,.~IELLHEAD = FMC SAFETY NOTES: ACtUAtOr: S 104 KB. ELEV = 64.50'! BF. ELEV = 38.22' KOP = 750' Max Angle = 57 @ 3230' ',', Datum MD = 9100' Datum TVD = 7000' SS ~ GAS LFI- MANDRELS H ~, '"~'--~'"'~ TVD ~ TYPE M--~-;LAT___CHPORT DATE I r--~ 5 4839 3495 54 KBG-2-T/L DOME' BK 16 0,12/01 :Minimum ID = 3.725" @ 8724' , ~ 6731 4883 31 KBG-2-T/L S/O BE 20 03/12/01 PRODUCTION MANDRELS 4-1/2" HES XN NIPPLE I ST MD TVD IDEV TYPE VLV LATCH PORT DATE 3 6920 5046 29 KBG-2-T/L DMY BK 0 02/07/01 17"MAF~ERJT(20')W/RATAGH 6499' }---"--11 2'7117 5218 30 KBG-2-T/L DMY BK 0 02/07/01 il 7266 5347 30 KBG-2-T/L DMY BK 0 02/07/01 i , , 14-1/2"TBGJT#40W/RA TAG Id I I I-- --~ 6842' H 4-1/2"HFR XNIP, ID= 3.813"I ~: ~"-I 68s3' H 7'X4'1/2"BKRSABL'3PKR'ID:3'875"I PERFORATION SUIVlMARY [~~ 7035' I~ 4'1/2" BKR CMU SLIDING SLV' OTIS PROF'i ID = 3'812" ' REF LOG: SWS PLATFORM EXPRESS GR/RES 01127101 ANGLE AT TOP PERF: 29 @ 6920' ~;~ 7061' 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" i Note: Refer to Production DB for historical perf data H SEE SPF INTERVAL Opn/Sqz DATE . ~ 7175' 4-1/2" BKR CMU SLIDING SLV, OTiS PROF, ID = 3.812" 4-5/8" 6 6920- 6980 O 02/04/01 H 4-5/8" 6 7018- 7050 O 02/04/01 ~ ~;~ "---~ 7201' 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875"I 4-5'8" 6 7070-7094 O 02'04'01 ' t 7333'I-t 4-1'2"BKRCMUSLDINGSLV OTISmOF,,D=3.812"J 4-5/8" 6 7114 - 7124 O 02/04/01 ' ' ' 4-518" 6 7162- 7182 O 02/94101 4-5/8" 6 , 7216-7266 O 02/04/01 4-5/8" 6 7280- 7302 O 02/04/01 4-5/8" 6 7325- 7346 O 02/04/01 3-3/8" 6 8810- 8840 O 03/26101 Iff I ~ ~ ~ 8679' 7"X 4-1/2" BKR SABL-3 PKR, ID: 3.875" :1 I-- ---{ 8703' H 4-1/2" HES X NiP, ID: 3.813" I , i----I "z"' Id 4-1/2" HES XN NIP' ID = 3'725" I 4-1/2"TBe, 12.6#,L-80,.0152bpf,,a=3.958"H 8736' ~-~ ~__~ 8736, H 4_I/2,,WLEG,,D=4.00,,i I H I I 7" CSG, 26#, L-80, M-BTC, D =6.276" H 9186' I I DATE REV BYICOMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT / AURORA FIELD 02/09/01 ORIGINAL COIVPLETION WELL: S-104 02/10/01 Cismoski CORRECTIONS PERMIT No: 200-1960 06/11/01 GRC/tb PERF CORRECTION . APl No: 50-029-22988-00 09/03/01 KSB/th NIPPLEID CORRECTION SEC 35, T12N, R12E, 4646' NSL & 4494' WEL 04~09~02 RN/CH/TP CORRECTIONS BP Exploration (Alaska) ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 6920 5046 29 KBG-2-T/L DMY BK 0 02/07/01 2 7117 5218 30 KBG-2-T/L DMY BK 0 02/07/01 1 7266 5347 30 KBG-2-T/L DMY BK 0 02/07/01 SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" 6 6920- 6980 O 02/04/01 4-5/8" 6 7018 - 7050 O 02/04/01 4-5/8" 6 7070- 7094 O 02/04/01 4-5/8" 6 7114- 7124 O 02/04/01 4-5/8" 6 7162 - 7182 O 02/94/01 4-5/8" 6 7216 - 7266 O 02/04/01 4-5/8" 6 7280- 7302 O 02/04/01 4-5/8" 6 7325- 7346 O 02/04/01 3-3/8" 6 8810- 8840 O 03/26/01 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/09/01 ORIGINAL COIVPLETION 02/10/01 Cismoski CORRECTIONS 06/11/01 GRC/tb PERF CORRECTION 09/03/01 KSB/th NIPPLEID CORRECTION 04/09/02 RN/CH/TP CORRECTIONS RE: S-104 APerfS-02.xls Subject: RE: S-104 APerf8-02.xis Date: Thu, 15 Aug 2002 19:12:40 -0500 From: "Young, Jim" <YoungJ3~BP.com> To: "Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us> CC: "Catron, Garry R (SIS)" <CatronGR~BP.com> Winton, Per Jody's request, heres a written confirmation that we need an approval on the S-104 Aperf/Reperf job by 8/16 since the crews may be able to get to it on Saturday. Garry, As soon as you hear back, please call Tyler Norene at 659-5710 or WL Compl supv. at x5584. Thanks Jim > ..... Original Message ..... > From: Catron, Garry R (SIS) Sent: Thursday, August 15, 2002 2:57 PM To: Young, Jim Subject: RE: S-104 APerfS-O2.xls Jim, AOGCC has put a rush on this application. Since you will be out tomorrow, who is contact person on slope for this job? Once I get the verbal go ahead, I will call them. Garry File: S-104 APerfS-O2.xls >> bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-66 ! 2 (907) 561-5111 August 15, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: RE: Sundry Notice for S-104 Add-Perforations (permit # 200-196). An add-perf is proposed in well S-104 using conductor line as soon as possible (est. 8/20/02). The existing 30' perfs are moderate quality reservoir and we are attempting to increase injection rate by increasing area open to flow. If you have any questions, please contact Jim Young, Aurora Petroleum Engineer, at 564-5754 or by email at Youngj3@bp.com. Sincerely[F-), Jim Young /~/~~ Aurora Petroleum Engineer Page 1 MEMORANDUM A TO: Cammy O Taylor ~J' Chairman THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 13, 2002 SUBJECT: Mechanical Integrity Tests BPX S Pad PBU Aurora NON- CONFIDENTIAL WellI S-104 P.T.D.I 200-1960 Notes: WellI S-107 P.T.D.I 201-130 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ITypolnj.I S I T.V.D. I 4988 I Tubing I 2000 I 2000 I 2000 I 2000 I lntervall I Type testI P I TestpsiI 1247 ICasingI 550 I 20201 20001 20001 P/F I P Type testI p I Testpsil 1660 1CasingI 1500I 2500I 2440I 2440I P/F I --P Type Inj. Type test Type Inj. Type test' IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXsS Pad and witnessed the initial MIT on wells S-104 and S-107. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Attachments: Number of Failures: 0 -- Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. MIT PBU S Pad 6-13-02 CS.xls 6/20/2002 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 2061 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 05/09/02 Field: Polaris Well Job # Log Description Date Color Sepia BL CD W-212 ~-0/o/~ 22184 PEX AlT BHC 04/06/02 1 W-212 22184 PEX-AIT 04/06/02 I 1 W-212 22184 !PEX-DEN/NEUTRON 04/06/02 I 1 W-212 22184 'PEX-TRIPLE COMBO 04/06/02 1 1 W-212 ',~ 22184 BHC 04/06/02 ] ] W-200 .J,C~ "7~,-~ J/"/ PRODUCTION PROFILE - 04/29/02 I 1 S-104 c:~(319 - / c) ~ SBHP SURVEY 04/11/02 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED 2002 Alaska Oil &GasCons. Camnmi n Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATrN: Sherrie Received ~ ~ bp .... BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 17, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-104 to Convert to Water Injection from Pre- Producer. BP Exploration Alaska, Inc. proposes to end the production from well S-104, ( a pre- produced injection well). This well will be converted to water injection commencing in the middle of May. Currently, this well is shut-in and freeze protected. The procedure includes the following major steps: Category IOR Step Description O 1 MITIA & In'jectivity test ( 300 bbls SW or PW ). 1. MITIA to 3000 psi & perform injectivity test @ 2000 and 2800 psi. a.) need 300 bbls of 2% KCL or seawater, (tubing volume +75 bbls for each pressure). 2. AOGCC witnessed MITIA within 1-2 weeks following injection startup. Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. Sincerely\,/ dim Youn Greater Prudhoe Bay Aurora Development Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Conversion to Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Water Injection Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 64.5 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic _ Anchora~le, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 633' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM (asp's 618931, 5980850) S-104 At top of productive interval 9. Permit number / approval number 1867' FNL, 5120' FEL, SEC 26, T12N, R12E, UM (asp's 618235, 5984885) 200-196 At effective depth 10. APl number 1710' FNL, 690' FEL, Sec. 27, T12N, R12E, UM (asp's 617383, 5985029) 50-029-22988-00 At total depth 11. Field / Pool 1712' FNL, 705' FEL, Sec 27 T12N, R12E, UM (asp's 617368, 5985026) Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured 9196 feet Plugs (measured) true vertical 7159 feet Effective depth: measured 9100 feet Junk (measured) true vertical 7064 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 108' 20" 260 sx AS (Approx) 136' 136' Surface .3718' 9-5/8" 585 sx AS Lite III, 355 sx 3736' 2863' Class 'G' Production 9160' 7" 270 sx AS Lite III, 243 9186' 7149' Class 'G' Perforation depth: measured Open Perf 6920'-6980', 7018'-7050', 7070'-7094', 7114'-7124', 7162'-7182', 7216'-7166', 7280'-7302', 7325'-7346', 8810'-8840' 1'~:? true vertical Open Perf 5046'-5099', 5132'-5160', 5177'-5198', 5218'-5224', 5257'-5274', 5304'-5347', 5359'-5378', 5398'-5416', 6777'-6807' /~. Tubing (size, grade, and measured depth 4-1/2" 12.6#, L-80 TBG @ 8679'. 4-1/2" 12.6# Tubing Tail to 8736'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker SABL-3 Packers @ 6853', 7061 ', 7201' & 8679' MD. 4-1/2" 'X' Nipple @ 2403'. 13. Attachments Description summary of proposal ~X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 1 1 Ma)/15, 2002 16. If proposal was verbally approved Oil ~ Gas _ Suspended __ Name of approver Date approved Service WATER INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jim Young @ 564-5754. Signed ~...~ ./) Title: Aurora Surveillance Engineer Date April 17, 2002 . JimYoun~l / / ~FOR COMMISSION USE ONLY Prepared by DeWm/ne R. Schnorr se4-s174 'Conditions of approval~ Notify Commission so representative may witness I Approval no. Plug integrity_ i~,OP Test_ Location clearance__I Mechanical Integrity Test~, Subsequent form required 10- Approved by order of the Commission [. /'~o~nmissioner Date , Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Pcr--~CHANICAL iNTEGRITY REPOaT · ':PUD :~_LL DATA Casing: 7 Liner .......... Shoe: ~ - .~ Packer 7 ~ ~ Hole Size [- $/~'" and TVD; TOP: T'~D; Sec a~ ! ; Perfs ~/90 TVD iNTEGRITY - P.~ZRT f! Annulus Press Testi ; ! 5 rain ; 30 min . Cemenc Bond Log (les or No) CBL Evaluation zone above perfs .,,,.', ~.~{ ',,.~,~.,.,,./~ ~:?,:,~. ,~;o' f, /:.~,,'~" ,,~.~ ....'"'~ ~.:::?'.~" ~' , .,~ Production Log: Type ........ Evaluation WELL LOG TRANSMITTAL To: State of Alaska February 05, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs S- 104, AK-MM- 10014 1 LDWG formatted Disc with verification listing. API#: 50-029-22988-00 PLEASE ACKNOWLEDGE RECEIPT iBY SIGNING AND iRETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 iBP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signe~a~, '(~~ ( i' //4' STATE OF ALASKA ,JAN ."L 5LOnn")~' C//uu./_,....,; , ~, ALASKA OIL AND GAS CONSERVATION COMMISSION ?..,. ~ I' APPLICATION FOR SUNDRY Al:}PFlOYAl~l~aoil&~asco~s.¢ommis~°~ ........ i. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ &,~,C,qC, Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Add Perfs Change approved program _ Pull tubing _ Variance _ Perforate X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 64.5 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchora~le, AK 99519-6612 Service_X Prudhoe Bay Unit 4. Location of well at surface ¢' ¢' ,~ 8. Well number 633' FNL, 4494' FEL, Sec. 35, T12N, R12E, UM (asp's 618931, 5980850) S-104 At top of productive interval 9. Permit number,~ approval number 1867' FNL, 5120' FEL, SEC 26, T12N, R12E, UM (asp's 618235, 5984885) 200-196 At effective depth 10. APl number 1710' FNL, 690' FEL, Sec. 27, T12N, R12E, UM (asp's 617383, 5985029) 50-029-22988-00 At total depth 11. Field / Pool 1712' FNL, 705' FEL, Sec 27 T12N, R12E, UM (asp's 617368, 5985026) Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured 9196 feet Plugs (measured) true vertical 7159 feet Effective depth: measured 9100 feet Junk (measured) true vertical 7064 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 108' 20" 260 sx AS (Approx) 136' 136' Surface 3718' 9-5/8" 585 sx AS Lite III, 355 sx 3736' 2863' Class 'G' Production 9160' 7" 270 sx AS Lite III, 243 Class 'G' 9186' 7149' Perforation depth: measured Open Perf 6920'-6980', 7018'-7050', 7070'-7094', 7114'-7124', 7162'-7182', 7216'-7166', 7280'-7302', 7325'-7346', 8810'-8840' true vertical Open Perf 5046'-5099', 5132'-5160', 5177'-5198', 5218'-5224', 5257'-5274', 5304'-5347', 5359'-5378', 5398'-5416', 6777'-6807' Tub ng (size, grade, and measured depth 4-1/2" 12.6#, L-80 TBG @ 8679'. 4-1/2" 12.6# Tubing Tail to 8736'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker SABL-3 Packers @ 6853', 7061', 7201' & 8679' MD. 4-1/2" 'X' Nipple @ 2403'. , , 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 1 1 January 16, 2002 16. If proposal was verbally approved Oil __ Gas _ Suspended _ Name of approver Date approved Service Pre-Producer 17. I hereby certify that ~,foregoing is t,~e and correct to the best of my knowledge. Questions? Call Jim Young @ 564-5754. Signed Title: Aurora Surveillance Engineer Date January 14, 200~2 Jim youn~ / / )f Prepared by DeWayne R. Schnorr 564-5174 / (.,. ( FOR COMMISSION USE ONLY Conditions of approval: Notify Commission ~'o representative may witnessII Approval no~.._ ~..~ Plug integrity_ BOP Test_ Location clearance__ --~___~-.~- Mechanical Integrity Test_ Subsequent form required 10- .Approved by order of the Commission ,., ..... n__L_,: Commissioner Date gOlllllly [,l~l, ll*311 - Form 10-403 Rev 0,6/15/88 · ORIGINAL SUBMIT IN TRIPLICATE bp i' BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 14, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-104 to Add Perfs (Kuparuk C-4 Sands) BP Exploration Alaska, Inc. proposes underbalanced perforating the Kuparuk C-4 Sands in Aurora development well S-104. Underbalance should be achieved by gas- lifting with the well open to LPS. The proposed perfs are in a Iow quality reservoir, so long clean perf tunnels are necessary to enhance flow. This well is being pre-produced before turning it into an injection well. The procedure includes the following major steps: Category IOR Step Description E 300 1 Perforate 20' of C4, lowest shot 8970 MD Last Test: FBHP: Max. Deviation: Peris: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: Tie in Log: BHP: 01/09/2002, 52 BOPD, 72.8% WC, 1.72MMscfd ALG 1900 psi 57° @ 3230' md Deviation at peris: 8° Present Peris 6920' through 8840' MD 3.725" at X nipple at 8724' MD 8900' MD (10/21/2001) N2 Injection, 12/09/2001 Not Tested (New well). OS well S-200 10 ppm 8/14/01. PEX GR (01/27/2001) Schlumberger USIT/GR. Est Res. Pres. 3000 psia @ 8800' MD @ 6767' TVDSS 1. Obtain Well test no less than 2-days prior to, and ASAP after perforating. 2. Open CK 100% with ~0.5MMcfd ALG ---) 1000 psi underbalance. E-Line , Perforate well, Zone C4 from 8950'-8970' MD, (6916'-6936' TVDss). Perforate using Schlumberger 3-3/8" HSD P J, 3406, 6SPF, 60 degree phasing, random orientation. Tie-into SWS USIT/GR. 4. POOH to s ,,~cy and then increase gas lift to 2.0 ,.,,cfd, for post-perf test. 5. Obtain Well test ASAP after perforating. Please call (Jim Young 564-5754, hm: 248-0133, oell: 440-8007) if there are any questions. Sincerely, Jim Young Greater Prudhoe Bay Aurora Development Engineer PERFORATING PROCEDURE Vet 4.0 06/O4/01 Well: S-104 APl #: 50-029-22988-00 Date: ...................... ~,~,,/~.,5,/,,.0,.1. ....................... Prod Engr,,,J.!.,m.,.,.,Y,,.o,..u...n..,g, .................... Office Ph: ........................... ..5...6...4,,-,.,5..,7,.,5,,.4, ........................... I! H2S Level: II Home Ph: 248-0133 .I <10ppm ............................................................................. ..~.. _,... ........ -. Cell/Pager: ........................... ....4~.....0;....8...0..,0...7. ........................... CC or AFC: 5M0009 Detail Code: 9335-070-770 Description:..D.R.L..G./...C...O..M.p.~..E~r~ ,!O...N.,./,...,P.,.E**.R..,.F' ................................................................................................................................................................................................................................................................. WBL Entries IOR Type Work Desciption 300 E Perforate 20' underbalanced Well Obiectives and Loc]~]inR Notes: Obtain Well test no less than 2-days prior to, and ASAP after perforating Well makes -700bopd, 0-50%wc, 2mmcfd ALG Attachment: Reference log with proposed perfs annotated, 5"/100' scale Schlum Depths (from-to) 8,970' Reference Log Tie in Log Log: PEX GR USIT Date: 1/27/2001 Company: SWS Depths (from-to) ......... ............... .,8.,,,,?,...0,, .............. , ,8, ,,, ,5. , , ,0. ,', ....... . . . . Add 0 to the tie-in log to be on depth with the reference log. Requested Gun Size: Feet SPF Orient. 20 6 . ............. N,.~, ............ At what Depth? .......... ,.3,.%3,./,,8,, ......... Charge: ............. ,p, j* *3. , ,4* * ,O, . .6* * ............ Desired Penetration: >20" Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check w/ Pad Operator to see if necessary piping Is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backftow Through Drain or Hardline) Tie in to Jewelry @ 8690 MD Tie in using: Minimum ID: ~,!, ~.,!,!.~ii~,,i, !,,,,in Min ID Type: Tail Depth: .......... ..8...6,..9,..0. .......... ff MD Casing Size: Est Res. Pres. @ Last Tag: ........ ,>,,,,8,,,9,,,0,,,0, ........ ff MD on ,,,~,~r~,~r~,,4 feet Well: S-104 Date: General Comments: Phasing Zone Ad/Re/Iperf ...... ,.C.,.4,. ....................... N/A Entry Hole Diam: >0.3" FOR FRAC MULTIPLE X-NIPPLES @ 'MD 7 in ....... ,,8.,,.,8,**0.,,0., ...... MD is ................ .,3...0.,.0,.,0,, psi Perforation Summary I~ Dis.._~t IF°wn: APl #: ......... 5,0,,-02,9;;2,,2,,.9,..8,..8.~..0.,,0' ........ Prod Engr: .............................................................................. IIAnch Prod Engr IIP.D. Center PBTD Depths Zone Aperf/Reperf Balance O/B/U O/B/U Referenced to BHCS - Gun Dia. Orient. SPF Phasing O/B/U O/B/U O/B/U TREE= 4-1/8" 5M WELLHEAD= FMC 11" ACTUATOR= KB. ELEV = 64.5' BF. ELEV = 35.9' ~KOP = 300'I IMax Angle = 54 @ 2200' Datum MD = 8798' ·., Datum TVD= 6700' SS 9-5/8" CSG, 40#, L-80 BTC, ID = 8.681"1'~1 3736' S-104 Minimum ID = 3.725" @ 8724' HES XN Nipple PERFORATION SUIVlVlARY REF LOG: Ref Platform Express GR/Res 01/27/01 ANGLE AT TOPPERF: 29 @ ...... Note: Refer to R'oductbn D13 for historical perf data SIZE SPF INTERVAL OpWSqz DATE 4-5/8" 6 6920 -6980 O 02/04/01 4-5/8" 6 7018 -7050 O 02/04/01 4-5/8" 6 7070 -7094 O 02/04/01 4-5/8" 6 7114- 7124 O 02/04/01 4-5/8" 6 7162 - 7182 O 02/04/01 4-5/8" 6 7216- 7266 O 02/04/01 4-5/8" 6 7280 - 7302 O 02/04/01 4-5/8" 6 7325 - 7346 O 02/04/01 3-3/8" 6 8810 - 8840 O 03/26/01 4-1/2" TBG, 12.6~ft, L-80 NSCT, ID= 3.958" H 8736' I o' oo' ; 7"CSG, 26#,L-80~BTC, ID=6.276"I---~ 9186' I J SAFETY NOTES: 2403' ~ x-r',IPPLE, D=3.813"I GAS LFT MA kI~RELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 5 4839 3495 54 KBG-2-T/L R!:) BK 02/07/01 4 6731 4883 31 KBG-2-T/L DMY BK 02/07/01 PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 3 6920 5046 29 KBG-2-T/L DMY BK 02/07/01 2 7117 5218 30 KBG-2-T/L DMY BK 02/07/01 1 7266 5347 30 KBG-2-T/L DMY BK 02/07/01 6842' H 4-1/Z' HES XNPPLE, ID=3.813" I 6853' H 7"X4-1/2"BAKE~;"SABL'3PKF~ID=3'938" I 7035' ~ 4-1/Z'BAKERCMUSLDINGSLV,OTISPROF., D=3.812" I 7061' H 7"X4'l/2"BAKERSABL-3PKR'ID=3'938" I 7175' 4-1/2-BAKER CMU SLIDING SLV, OTIS PROF., ID = 3.812" I 7201' 7333' H 7 "X4-1/Z' BAKERSABL-3PKI~ ID= 3.938" I--I 4-1/2,, BAKER CMUSLIDING SLV, OTIS PROF, ID=3.812" I 8679' I'~1 7" X 4-1/2" BAKER SABL-3 PKI~ ID = 3'938" I 8703' H 4-1/2"I-ESXNIPFLE'ID:3'813" i 8724' H 4-1/2" I-ES XN NIFPLE ID= 3.725" 8736' H 4-1/Z' WLEGI DATE REV BY COMMENTS DATE REV BY COMMENTS 01/08/01 P. Smith OriginaIProposed Completion 02/09/01 P. Smith lAs-Completed 02/10/01 Cismoski CORRECTIONS 06/11/01 GRC/tlh PERF CORRECTION 09/03/01 KSB/tlh NIPFLE D CORRECTION PRUDHOEBAY UNIT/AURORA FELD WELL: S-104i PERMIT No: 200-196 APINo: 50-029-22988-00 Sec. 35, T12N, R12E, 4494' FEL, 633' FNL BP Exploration (Alas ka) o. ^ ASKA ! ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR "ECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Pre-Produced Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 200-196 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22988-00 14. Location of well at surface ~~: 9. Unit or Lease Name 4646' NSL, 4494' WEL, SEC. 35, T12N, R12E, UM i~ ,~;'.'~"."'."'..::7:0!,',i:v..: .': . 'i!!LOC. ATfOf~[ VIl[;liJrd]~~; Prudhoe Bay Unit At top of productive interval 3412' NSL, 5120, WEL, SEC. 26, T12N, R12E, UM ! .~--:--~-.:-r-.~--L ! i .... '~':i'~:::;:ri ' ~ 10. Well Number 3567' NSL, 705' WEL, SEC. 27, T12N, R12E, UM , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Aurora Pool RKB - 64.5' ADL 028258 12. Date Spudded 1/11/2001 113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'l/26/2001 2/9/2001 115' water depth' if °ffsh°re N/A MS L 116' N°' Of C°mpleti°ns One 17. Total Depth (MD+TVD) 118, Plug Back Depth (MD+TVD) 119, Directional Survey 1 20. Depth where SSSV set1 21, Thickness of Permafrost 9196 7159 FTI 9100 7064 FTI [] Yes [] NoI (Nipple) 2403' MDI 1900' (Approx,) 22. Type Electric or Other Logs Run MWD, GR, Res, PWD, RES/ALT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, Sonic, CMR, FMI, RFT, USIT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 108' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 28' 3736' 12-1/4" 585 sx Arcticset Lite III, 355 sx 'G' 7" 2'6# L-80 26' 918'6' 8-3/4" 270 sx Arctic set Lite III, 243 sx 'G' ,, , , , , 24. Perforations op. en to Product[on (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) ........................ SIZE DEPTH SET (MD) 'PACKER SET (MD) 4.63" Gun Diameter, 6 spf 3-3/8" Gun Diamter, 6 spf ' ' 4-1/2", 1216#,'L-80 " 8736' ' .... 8679' MD TVD MD TVD ................... 6920'- 6980' 5046'- 5099' 8810'- 8840' 6777' - 6807' . .......... 7018' - 7050' 5132' - 5160' ~6': ACID, FRACTURE, CEMENT SQUEEZE, ETC. , 7070 - 7094' 5177' - 5198' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7114' - 7124' 5218' - 5224' 7162' - 7182' 5257' - 5274' 2000' (Approx.) ' Freeze Protect with 85 Bbls of 'Diesel 7216' - 7166' 5304' - 5347' 7280 - 7302' 5359' - 5378' 7325'- 7346' 5398' - 5416' 881 o' - 8840' 6777' - 6807' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 03/27/01 Gas Lift 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 3-28-2001 4 TEST PERIOD 749 349 0 176I 466 Flow Tubing Casing Pressure CALCULATED OIL'BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit I ECE cor , ~VEO See Attached. MAY 01 ZOO1 Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Ugnu 5014' 3598' Top Shrader Bluff 6642' 4807' CA 7018' 5132' OB 7070' 5177' CMl 8290' 6268' THRZ 8668' 6636' BHRZ/TKupD 8769' 6737' Top Kuparuk C 8782' 6749' LCU/TKupB 8970' 6936' Kup. RECEIVED Kup. A4 9034' 6999' Uiluveach 9074' 7038' Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Core Description, Formation Integrity Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,,,~~.~, ~ Title TechnicalAssistant .. Date S- 104i 200-196 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BPX Exploration, Alaska S-104i Well Core Description Aurora Field Core gl: 8765'-8853'. Cut 88', recovered 88'. Well bore inclination was 8 degrees from vertical. 8765'-8779': Shale, dark brownish black, with quartz and glauconite sand grains, sand content increasing downward, slightly pyritic. Fissile and hard above, becoming subfissile to blocky in lower section. 8779'-8790': Sandstone, medium to dark brown, very glauconitic, very argillaceous, medium grained, siderite cement, low porosity and permeability, patchy oil stain. 8790'-8795': Sandstone, medium brown, 10-20% glauconite, medium grained, well sorted, siderite cement, good porosity, uniform oil stain. 8795'-8753': Sandstone, medium brown, glauconite content decreases downward from 10-15% to 3-4%, very fine to fine grained, well sorted, siderite cement, good porosity and permeability, uniform oil stain. Core #2: 8853'-8935'. Cut 82', recovered 82'. Well bore inclination was 8 degrees from vertical. 8853'-8870': Sandstone, medium brown, slightly glauconitic, slightly argillaceous, very fine to fine grained, well sorted, moderate silica and siderite cementation, porosity ranges from good to fair, generally decreasing downward, uniform oil stain. 8870'-8910': Sandstone, medium brown, argillaceous (increasing clay content downward), trace glauconite and fine coaly debris, silty, very fine grained, well sorted, moderately well to well cemented with silica and siderite, low porosity and permeability, irregular oil stain (decreasing downward). 8910'-8935': Siltstone, medium to dark brown, sandy and argillaceous, slightly glauconitic, very low porosity and permeability. Concentration of glauconite at 8925'- 8926'. Legal Name: S-104 Common Name: S-104 :~ :: :~:i AMW:ii:: = SurfaCe Pressure Leak Off Pressure (BHP) EMW 1/18/2001 FIT 3,735.0 (ft) 2,862.0 (ft) 10.50 (ppg) 317 (psi) 1,878 (psi) 12.63 (ppg) Printed: 5/1/2001 1:40:58 PM BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: ELEC Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code '1/28/2001 00:00 - 10:00 10.00 EVAL PROD1 Schlumberger Log hole from 9100'-3735' w/Run #2. FMI-DIPOLE-SONIC @ 850'/hr. POOH with e-line from 3735'. 10:00 - 11:30 1.50 EVAL PROD1 RID Schlumberger E-line sheaves and related equipment. Printed: 2/26/2001 3:09:15 PM BP EXPLORATION Page 2 of 10 Operations Surnma Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/10/2001 10:00 - 12:00 2.00 RIGD POST Load and move work shop. Move camp. Load and move pit module away from rig. 12:00 - 14:00 2.00 RIGD POST Move rig from over well S-213. 14:00 - 16:00 2.00 RIGU PRE Lay mats and Herculite around well S-104i. Move rig into position over well S-104i. Spot pit module. Start taking on Water. Rig accepted @ 16:00 Hrs. 16:00 - 00:00 8.00 RIGU PRE R/U Nabors 9ES to drill. N/U 20" riser on well. Finish taking on water & spud mud. N/U Flow riser & Dresser sleeve. Bring Bha subs,X/O and bit to rig floor - steam and caliper. Service Top Drive. Hold Pre-Spud meeting. 1/11/2001 00:00 - 01:00 1.00 RIGU PRE Spud Meeting with Rig Crew & all Svc. Co. personnel. Also discussed, in depth, Tony's e-mail re. PJSM's. 01:00 - 04:00 3.00 RIGU PRE Fill hole, check for leaks, M/U Spud BHA ¢1, Prime pumps check all lines. 04:00 - 07:00 3.00 DRILL SURF Spud well. Tagged @ 102'. Drill to 230'. All Rotate. 07:00 - 08:30 1.50 DRILL SURF POH w/BHA ¢ 1, M/U BHA ¢ 2 for Kick - Off. MWD failed test. 08:30 - 13:00 4.50 DRILL DATA SURF CIO MWD also problems with signal from tool. Sperry working on problem - isolated all interference, finally got good signal. 13:00 - 14:00 1.00 DRILL SURF RIH to 230'. Circ. & Reciprocate while rigging up Gyro. 14:00 - 14:30 0.50 DRILL SURF Run Gyro Survey: 14:30 - 17:00 2.50 DRILL SURF Directional Drill from 230' to 309' All Slide. 17:00 - 17:30 0.50 DRILL SURF Run Gyro Survey 17:30 - 20:00 2.50 DRILL CIRC SURF Outside sprocket broke on Cuttings Drag Chain. Replace same. 20:00 - 00:00 4.00 DRILL SURF Directional Drill from 309' to 447'. ART = 3/4 Hr. AST = 3 1/2 Hr. WOB 1 -20 K, 425 gpm., 800 psi. 1/12/2001 00:00 - 00:00 24.00 DRILL SURF Drill 12 1/4" Directional Hole from 477' to 1516'. AST = 11 3/4 Hrs.ART = 4 Hrs. 1/13/2001 00:00 - 08:00 8.00 DRILL SURF Drill from 1516' to 1888' ART = 1.5 Hrs. AST = 5.75 Hrs. Poor ROP - 46' per Hr. 08:00 - 09:00 1.00 DRILL SURF Circlulate Hole Clean 09:00 - 10:30 1.50 DRILL SURF POH w/DP & HWDP. Hole slick, no problems. 10:30 - 13:00 2.50 DRILL SURF CIO Bit & reconfigure BHA. 13:00 - 14:00 1.00 DRILL SURF RIH to 1794' Wash to 1888'. No Fill. 14:00 - 00:00 10.00 DRILL SURF Drill directionally from 1888' to 2446'. ART = 2 Hrs. AST -- 4 Hrs. Average 93 ft. per Hour. 1/14/2001 00:00 - 14:00 14.00 DRILL SURF Drill from 2446' to 3750' AST -- 4.25 ART -- 6.25 Casing point per geologist. 520 gpm, 80 rpm 10 - 30 K on Bit., Avg. - 124 ft./Hr. 14:00 - 15:30 1.50 DRILL SURF Circulate Hole Clean 15:30 - 19:00 3.50 DRILL SURF POH, Tight 2700 -2630, 2300 -2360, Washed through, but would not clean up for pulling dry. POH wi 20 - 30K overpull. 19:00 - 00:00 5.00 DRILL SURF Stand back HWDP. LID MWD & Bit. Stab., bit & MWD balled up w/ clay. Clean floor, P/U Tools for BHA¢4 & make up 12 1/4" Smith" Porcupine" Hole Opener. 1/15/2001 00:00 - 01:00 1.00 DRILL SURF M/U BHA ¢4 ( Hole Opener Assy.) 01:00 - 02:00 1.00 DRILL SURF RIH, Took weight at 1920' 02:00 - 04:00 2.00 DRILL SURF Ream from 1920' to 2680', wash to 2756' 04:00 - 05:30 1.50 DRILL SURF Continue RIH to 3697', Wash to TD - 3750'. 05:30 - 08:30 3.00 DRILL SURF Circ. Hole Clean with weighted, Hi Vis, Barofiber Printed: 2/26/2001 3:09:15 PM BP EXPLORATION Page 3 of 10 Operations Summa Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NAB©RS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/15/2001 05:30 - 08:30 3.00 DRILL SURF Sweeps. Drop ESS Tool. 08:30 - 12:00 3.50 DRILL SURF POH - Take check surveys @ 3641', 3548', & 2608'. Open Hole slick - 15 K Max overpull. 12:00 - 14:30 2.50 DRILL SURF LID BHA, clean floor, L/D Tools. 14:30 - 15:30 1.00 CASE SURF PJU to run 9 5/8" Casing. 15:30 - 16:00 0.50 CASE SURF Hold PJSM w/Rig crew, casers & Nabors Roughneck Trainer, Tony Escobar. 16:00 - 16:30 0.50 CASE SURF Make Dummy run w/casing hanger and landing joint. Mark same. 16:30 - 00:00 7.50 CASE SURF Run 91 Jts.- 9 5/8" 40 ppf., L-80, BTC Casing. Shoe @ 3736', Float Collar @3655', Tam collar @ 1008'. Centralized as per program. Wash last jt. to setting depth. No fill. Weight Prior to landing - 172K up and 93 K dh. Full returns while running casing and circulating. 1/16/2001 00:00 - 02:00 2.00 CEMT SURF Circ. & Cond mud @ 6 bpm. - 380 psi. 02:00 - 02:30 0.50 CEMT SURF Break out Frank's tool. M/U Cement Head and lines 02:30 - 03:00 0.50 CEMT SURF PJSM with crew, Dowell, Baroid & Peak ( cont. circ ) 03:00 - 07:00 4.00 CEMT SURF Pump 5 bbl water, test lines to 4000 psi., pump 5 bbls water. Pump 75 bbls MUDPUSH XL Spacer. Drop bottom plug. pump 454 Bbls. lO .7 ppg. ASlII Lite Lead, followed by 73 bbls. 15.8 ppg. G Tail. Displace w/277 bbls mud. Bump plug w/3500 psi 37 bbls contaminated cement and 91 bbls good cement to surface. 07:00 - 07:30 0.50 CEMT SURF Flush Retarder through flow line, riser and all valves. Clean possum belly and shaker beds. 07:30 - 08:30 1.00 CASE SURF Rig down casing equip., landing Jt. & cement head. Change bails. 08:30 - 11:00 2.50 CASE SURF R/D flow riser, XO spool, change 16' boot. 11:00 - 17:30 6.50 CASE SURF Install FMC GEN-5 11" 5M Unihead system and test to 1000 psi. N/U 11" 5M x 13 5/8" 5M DSA flange + 13 5/8" 5M BOPE. 17:30 - 19:30 2.00 BOPSUR BARR SURF Repair BOP Test Pump 19:30 - 00:00 4.50 BOPSUF~ SURF Test BOP & all related equipment to 250/3500 psi. John Crisp, AOGCC witnessing. 1/17/2001 00:00 - 03:00 3.00 BOPSUF; SURF Complete BOP Test Lower T/D safety valve leaked. Change out and re-test OK Test witnessed by John Crisp; AOGCC. 03:00 - 04:00 1.00 BOPSUI; SURF N/D Test Equip.& lines, Run W/R 04:00 - 05:00 1.00 CASE SURF Rig up & Test Casing to 3500 psi under blind rams for 30 minutes. - OK 05:00 - 10:00 5.00 DRILL SURF P/U 5' DP & stand back in derrick - 34 stands 10:00 - 12:00 2.00 DRILL 'INT1 PJSM, M/U BHA # 5, Rotary Steerable.Test tools. Had MWD Resistivity Tool failure. 12:00 - 13:00 1.00 DRILL TEST INT1 Change out MWD-Resistivity tool. 13:00 - 15:30 2.50 DRILL INT1 Finish M/U BHA & HWDP. 15:30 - 18:00 2.50 DRILL INT1 TIH w/8.75" Sperry-Sun Rotary Steerable Drilling assembly + P/U 78 Jts 5" DP. 18:00 - 20:30 2.50 DRILL INT1 Slip & Cut Drlg. Line. Re-set and check C-O-M. Service Top Drive. Replace brake pad on draw works 20:30 - 21:30 1.00 DRILL INT1 Cont. TIH, Wash dn. from 3558'. Tag Cement at 3640'. 21:30 - 00:00 2.50 DRILL INT1 Drill cement to 3654' Drill plugs & float collar to 3556' Needed to be very cautious as pieces of the plugs and cement tended to pack off around Geo Pilot tool and rollers. A 250 psi differential pressure would damage the seals on the Geo -Pilot. 1/18/2001 00:00 - 01:30 1.50 DRILL SURF Continue Drilling out 9 5/8" Shoe Track and clean out 12 1/4" Rat Hole Printed: 2/26/2001 3:09:15 PM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/18/2001 00:00 - 01:30 1.50 DRILL SURF to 3750'. 01:30 - 02:00 0.50 DRILL SURF Drill 8.75" hole from 3750' to 3770'. 02:00 - 03:00 1.00 DRILL SURF PJSM CIO mud to 10.5 ppg., 4% KCL 03:00 - 03:30 0.50 DRILL SURF Perform FIT. Pressure to 317 psi -- 12.63 EMW Reservoir mtg w/Geologist, crew, Baroid & Sperry 03:30 - 21:00 17.50 DRILL INT1 Drill from 3770 to 5247. Actual rotating Hrs = 13.75 WOB - 3 to 7 K, 120 to150 RPM @ 450 GPM, Avg. ROP = 109 fi/hr 21:00 - 22:00 1.00 DRILL INT1 Circ. around Hi-Vis sweep. 22:00 - 22:30 0.50 DRILL INT1 POH, initial 20 - 30 K overpull, trying to swab, work out to 5100', 30 to 60 overpull to 4964'. unable to pull further without swabbing. Engage Top Drive. 22:30 - 00:00 1.50 DRILL INT1 Backream from 4964' to 4406'. No problems with pump and rotary. Seeing quite a bit of clay over shakers. Large OD ( 7 5/8" ) of Geo-Pilot and rollers that extend 9 5/8", along with a bit that has 13" of guage exacerbate any swabbing tendacies. 1/19/2001 00:00 - 01:00 1.00 DRILL INT1 Backream from 4406' to 3970'. POH to shoe @ 3735' 01:00 - 01:30 0.50 DRILL INT1 Service Top Drive. 01:30 - 02:30 1.00 DRILL INT1 RIH to 5153'. Fill pipe & wash down to 5247' Hole slick - No Fill. 02:30 - 00:00 21.50 DRILL INT1 Drill 8 3/4" Directional hole from 5247' to 6400'. Total on bottom drilling Hrs = 14.75. Avg ROP.= 78 fi/hr WOB: 5-13 K, 480 GPM, 130 RPM. 1/20/2001 00:00 - 04:00 4.00 DRILL INT1 Drill 8.75" hole from 6400' to 6710' ADT =2 hrs WOB = 5 - 13 K, RPM = 130, GPM = 485 04:00 - 05:00 1.00 DRILL INT1 Circ. Hi Vis sweep. 05:00 - 08:00 3.00 DRILL INTI Wiper Trip - POH to 5650', 10 to 70 K overpull, work each stand to avoid swabbing. Backream 5650' to 5400' & 5150' to 4800' 08:00 - 09:30 1.50 DRILL INT1 RIH to 6647', wash to 6710, Hole slick - no fill. 09:30-00:00 14.50 DRILL INT1 Drill 8.75" holefrom 6710' to 7650' ADT = 11 hrs. WOB=5-15K, ROT. = 130 GPM = 495 - 525 1/21/2001 00:00 - 04:30 4.50 DRILL INT1 Drill from 7650' to 8015' ADT = 3.25 hrs. 04:30-06:30 2.00 DRILL INT1 C&CMud. Make a 2/3 dilution with 560 bbls of new10.5 ppg 4%Kcl Mud. 06:30 - 14:00 7.50 DRILL INT1 Drill from 8015' to 8517' ADT = 3.5 hrs 14:00 - 15:00 1.00 DRILL INT1 Circulate Hi Vis sweep. 15:00 - 17:30 2.50 DRILL INT1 Wiper trip. POH 13 stds to 7302' w/max 30 K overpull. At 7302' pulled 60 K over, hole swabbing. Backream from 7302' to 6550' w/400 gpm @ 1400psi, 110 rotary. i17:30 - 19:00 1.50 DRILL INT1 RIH to 8424', wash to 8517'. Hole slick, no fill. 19:00 - 21:30 2.50 DRILL INT1 Drill from 8517' to 8678' 21:30 - 22:30 1.00 DRILL INT1 Circulate while geologists study logs and samples. 22:30 - 00:00 1.50 DRILL INT1 Drill from 8678' to 8765'. TD of coring point per Bob Dawson, Project Geologist. Total actual drilling time for section 8328 to 8765 was 4.25 Hrs. Drilled w/5 to 10 K on bit, 140 RPM, and 525 GPM. 1/22/2001 00:00 - 01:30 1.50 DRILL INT1 Take survey, circ. Hi Vis sweep 01:30 - 05:30 4.00 DRILL INT1 Wiper trip to shoe @ 3735'. POH to 6500 smooth. 6500 to 6300 - 20 K over, worked throughOK,4690' - tight - 40 K over. 05:30 - 10:00 4.50 DRILL INT1 Backream from 4690 to 4500 with difficulty - attempting to packoff - worked through cautiously, backreamed from 4500 to 3735 with little problem. 10:00 - 10:30 0.50 DRILL INT1 circ. @ 550 gpm in shoe to clean up. 10:30 - 13:30 3.00 DRILL INT1 Wipe hole down through trouble spots to 5059. Pull back into shoe - no Printed: 2/26/2001 3:09:15 PM BP EXPLORATION Page 5 of 10 Operations Surnma Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/1012001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/22/2001 10:30- 13:30 3.00 DRILL INT1 aroblem 13:30 - 15:30 2.00 DRILL INT1 Clean mud pits and take on 560 bbl fresh KCL mud. Cut & Slip Drilling line. Service T.D. to include changing dies in gripper while cleaning pits. 15:30 - 19:00 3.50 DRILL INT1 Complete original wiper trip - RIH to 8706' 19:00 - 22:00 3.00 DRILL INT1 Wash down from 8706 to 8765 - 5' fill on bottom. Pump Hi Vis spacer and displace well bore with 10.5 ppg 4 % KCL new Mud. displaced @ 500gpm at 1950 psi., Pump dry job. 22:00 - 00:00 2.00 DRILL INT1 POH -slowly 5 - 10 K drag, no swabbing. 1/23/2001 00:00 - 04:00 4.00 DRILL INT1 POOH with 5" DP to BHA. No hole problems encountered. Hole slick. 04:00 - 07:00 3.00 DRILL INT1 Stand back HWDP in derrick. Held PJSM. LID Jars, download MWD data, LID MWD and Geo-Pilot tool. 07:00 - 07:30 0.50 DRILL INT1 Clean Rig Floor. 07:30 - 11:30 4.00 EVAL PROD1 Held PJSM. M/U BHI 8.5" x 90' Core Barrel assembly with 4" inner core sleeve. ( run #1. ). 11:30 - 13:00 1.50 EVAL PROD1 TIH with 8.5" Core Barrel assembly on 5" DP to 3690'. 13:00 - 14:00 1.00 EVAL PROD1 Break circulation. CBU from 3690' w/400 GPM @ 750 psi. 14:00 - 15:30 1.50 EVAL PROD1 TIH to 6990' with no problems. 15:30 - 16:00 0.50 EVAL PROD1 Break circulation. Circulate 20 minutes wi400 GPM @ 1100 psi. No mud losses observed. 16:00 - 17:00 1.00 EVAL PROD1 TIH to 8672' with no problems. Hole slick. 17:00 - 17:30 0.50 EVAL PROD1 Establish circulation. Wash and Ream to bottom @ 8765'. No fill on bottom. 17:30 - 19:00 1.50 EVAL PROD1 CBU from 8765'. 330 GPM w/990 psi. P/U 225k-245k, Rot Wt 173k, 80 RPM w/13-14k torque. Drop 1" ball. Continue to circulate w/350 GPMuntil ball seated in the top of inner core barrel. 19:00 - 00:00 5.00 EVAL PROD1 Cut Core #1 From 8765' to 8780'. WOB 4-14k, RPM 50-80 w/12-14k ftlb torque, GPM 328 w/1300 PSI. 1/24/2001 00:00 - 02:30 2.50 EVAL PROD1 Continue to Cut core #1 from 8780' to 8853' ( 88' total core length ). WOB 4-14k, RPM 50-80/12-17k ftlb Torque, GPM 320 W/1300 psi. 02:30 - 12:30 10.00 EVAL PROD1 POOH with core #1. Pull at normal trip speed from TD up to 3000'. Trip speed F/3000'-1000' @ 3min/std., F/1000'-300' @ 6 min/std, F/ 300'-surface @ 15 min/std. 12:30 - 14:30 2.00 EVAL PROD1 Held PJSM. LID and recover Core #1. Had a 100% recovery ( 88' + ) of core samples. 14:30 - 15:00 0.50 EVAL PROD1 Clean Rig Floor. 15:00 - 16:30 1.50 EVAL PROD1 Redress Core Barrel. M/U Core Assembly #2. 16:30 - 18:30 2.00 EVAL PROD1 TIH with 8.5" Core Assembly #2 on 5" DP to 3735'. 18:30 - 20:00 1.50 EVAL PROD1 CBU from 3735'. Circulate w/246 GPM @ 450 psi. 20:00 - 23:00 3.00 EVAL PROD1 Continue TIH to 8759' with no problems. Broke circulation at 6900'. 23:00 - 00:00 1.00 EVAL PROD1 Establish circulation. Wash F/8759' to 8853'. Tag-up at 8853' TD. Reciprocate pipe and CBU. Circulate w/305 GPM @ 1136 psi. P/U wt. 238k, S/O 134k. 1/25/2001 00:00 - 00:30 0.50 EVAL PROD1 Finish CBU F/8853'. 305 GPM wi1136 psi. Drop 1" ball. Circulate and seat ball in top of inner core barrel. 00:30 - 04:30 4.00 EVAL PROD1 Cut Core #2 F/8853'-8933'. WOB 2-10k, RPM 70 w/15-18k ftlb Torque, GPM 305 w/1300 psi. P/U 240k, S/O 134K, Rot Wt 174k. 04:30 - 05:30 1.00 EVAL PROD1 Pump out of 8.5" Rat Hole up to 8765'. Flow Check well-OK. Pump slug. 05:30 - 13:30 8.00 EVAL PROD1 POOH with Core #2. Pull at normal trip speed F/8765' up to 3000'. Trip speed F/3000'-1000' @ 3 min/std., F/1000'-300' @ 6 min/std., F/ 300'-surface @ 15 min/std. 13:30 - 16:30 3.00 EVAL PROD1 Held PJSM. LID and recover Core #2. Had a 100% recovery ( 82.6' ) of core samples. Printed: 2/26/2001 3:09:'15 PM BP EXPLORATION Page 6 of 10 Operations Summa Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/25/2001 13:30- 16:30 3.00 EVAL PROD1 16:30 - 18:00 1.50 EVAL PROD1 L/D Core Barrel assembly and related equipment. 18:00 - 19:00 1.00 DRILL PROD1 Pull Wear Bushing. PJU to test BOPE with 5" DP. 19:00 - 21:00 2.00 DRILL PROD1 Test BOPE and all surface related equipment to 250/3500 psi. ( Leu Grimaldi of the AOGCC witnessed the test ). All test were APl. 21:00 - 22:00 1.00 DRILL PROD1 RID BOPE test equipment. Install Wear Bushing. 22:00 - 00:00 2.00 DRILL PROD1 M/U 8.75" Rotary Drilling assembly with MWD. 1/26/2001 00:00 - 00:30 0.50 DRILL PROD1 Finish M/U 8.75" Rotary Drilling assembly. 00:30 - 01:30 1.00 DRILL PROD1 TIH with 8.75" Drilling assembly on 5" DP to 3726'. 01:30 - 03:00 1.50 DRILL PROD1 Slip and Cut Drlg line. Re-set and check C-O-M. Service Top-drive. 03:00 - 08:00 5.00 DRILL PROD1 TIH to 8730' with no problems. 08:00 - 11:30 3.50 DRILL PROD1 Establish circulation. Wash, ream and perform MADD Pass from 8730' to 8933'. Had no problem reaming through the 8.5" core interval from 8765' to 8933'. 11:30-18:00 6.50 DRILL PROD1 Drill 8.75" hole from 8933' to 9196' MDTD / 7159' TVD ( 9196' is 7" casing point ). ART - 5.5 hrs. 18:00 - 19:30 1.50 DRILL PROD1 Pump Hi-vis pill and circulate hole clean from 9196'. 19:30 - 20:30 1.00 DRILL PROD1 POOH for wiper trip. Encountered tight hole @ 8990'. Pulling 100k-135k ( 350k-375k on wt indicator ) over normal P/U wt. 20:30 - 22:00 1.50 DRILL PROD1 Backream tight hole from 8980' to 8700'. GPM 420 w/1700 psi, RPM 110 w/16-18.5k Torque, RotWt 175k. ECD 11.45 ppg. 22:00 - 23:30 1.50 DRILL PROD1 Continue POOH 17 std to 7650' with drag decreasing to 225k-275k. 23:30 - 00:00 0.50 DRILL PROD1 TIH ( 8117' @ Midnight ). 1/27/2001 00:00 - 01:00 1.00 DRILL PROD1 TIH to 8680' with no problems. 01:00 - 02:00 1.00 DRILL PROD1 Establisn circulation. Ream from 8680' to 9196'. WeB 2k-5k, RPM 110, GPM 528 w/2550 psi. 02:00 - 03:30 1.50 DRILL PROD1 Pump Hi-vis sweep. Circulate and condition mud. GPM 528 w/2550 psi. 03:30 - 09:30 6.00 DRILL PROD1 Flow check well-OK. Pump slug. Drop 2.5" drift down 5" DP. POOH with no problems. Max drag 15k over normal overpull. 09:30 - 13:30 4.00 DRILL PROD1 PJSM. LID Flex collars. Download MWD Data. LID MWD tools and bit. 13:30 - 14:00 0.50 DRILL PROD1 Clean rig floor. 14:00 - 14:30 0.50 EVAL PROD1 Held PJSM with Schlumberger and Rig Crew regarding E-Line R/U and operations. 14:30 - 15:30 1.00 EVAL PROD1 R/U Schlumberger E-Line equipment. 15:30 - 20:00 4.50 EVAL PROD1 M/U Logging tool #1. "PEX ". RIH with same to 9160' e-line depth. Log well up to 9 5/8" casing shoe @ 3735'. POOH with e-line. 20:00 - 21:00 1.00 EVAL PROD1 PJSM. Change-out logging tool from PEX to FMI-DIPOLE-SONIC. 21:00 - 00:00 3.00 EVAL PROD1 Schlumberger RIH with log # 2. FMI-DIPLOE-SONIC to 9100'. 1/28/2001 11:30 - 12:30 1.00 EVAL PROD1 Held PJSM with Rig Crews prior to DPC Logging. 12:30 - 14:00 1.50 EVAL PROD1 M/U RFT-CMR Logging tools on 5" Drill Pipe. 14:00 - 16:00 2.00 EVAL PROD1 TIH with DPC Logs, run #3. RFT-CMR to 3720'. Break circulation w/ 123 GPM @ 170 psi. P/U 110k, S/O 87k. 16:00 - 19:30 3.50 EVAL PROD1 Continue TIH with RFT-CMR on 5" Drill Pipe to 5498'. Break Circulation every 5 stands. 19:30 - 20:00 0.50 EVAL PROD1 Install Schlumberger DHWC sub in 5" DP. R/U E-line and hang upper wire line sheave in Derrick. 20:00 - 22:30 2.50 EVAL PROD1 Schlumberger RIH with e-line and PDWC. Latch up to DHWC sub. 22:30 - 00:00 1.50 EVAL PROD1 TIH from 5498' logging hole with DPC RFT-CMR to 6674'. 1/29/2001 00:00 - 17:00 17.00 EVAL PROD1 SWS continue logging. TIH with DPC RFT-CMR taking formation pressure reading ( 45 total ) to 9130'. Took one fluid sample from 8967'. BHP at 8990' MD/6891' TVDSS = 3484 PSI. BHST = 148 deg. No hole problems encountered while logging down. Printed: 2/26/2001 3:09:15 PM BP EXPLORATION Page 7 of 10 Operations Sumrna Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/29/2001 17:00 - 00:00 7.00 EVAL PROD1 POOH from 9130' @ 300'/HR logging with the RFT-CMR tool ( Logging with CMR only ) up to 7369'. No hole problems while logging up. Drill String P/U Wt = 245k @ 9130'. 1/30/2001 00:00 - 08:00 8.00 EVAL PROD1 Log w/RFT/CMR tool @ 300'/hr from 7369'-5487'. No problems. 08:00 - 09:30 1.50 EVAL PROD1 POH to side entry sub. POH w/E-line & RD wireline. 09:30 - 12:00 2.50 EVAL PROD1 Pump dry job. POH to shoe w/no problems. D1 Drill-OS-l:45. 12:00 - 12:30 0.50 EVAL PROD1 Monitor well @ shoe-OK. Continue POH to logging tools. 12:30 - 14:30 2.00 EVAL PROD1 PJSM w/SWS. POH & LD logging tools. Clear & clean floor. 14:30 - 15:30 1.00 DRILL PROD1 Service top drive, crown, & rotary bushing locks. 15:30 - 17:00 1.50 DRILL PROD1 Monitor well. PJSM. PU & MU clean out assembly. Porcupine mill hole opener. 17:00 - 18:00 1.00 DRILL PROD1 RIH to 3700'. 18:00 - 19:30 1.50 DRILL PROD1 Break circ. Stage pumps up slowly to 525 gpm w/1395 psi. Circ & cond while monitoring returns. PU 113k; SO 88k. Monitor well-OK. 19:30 - 00:00 4.50 DRILL PROD1 RIH slowly, monitoring returns. RIH to 8834'. PU 250k; SO 127k. 1/31/2001 00:00 - 00:30 0.50 DRILL PROD1 Precautionary wash f/8824'-9115'. Wash & ream to 9196'. No noticeable fill. 00:30 - 02:00 1.50 DRILL PROD1 Rotate & reciprocate while circ sweep around. 110 rpm & 525 gpm w/ 2300 psi. 02:00 - 05:30 3.50 DRILL PROD1 Pump slug. POH to shoe. Pulling 5k-15k over off bottom; 25k-35k over @ 9000', 8980', & 8910'; 5k-10k over f/8900'-8870'. Pulled good the rest of the way to shoe. 05:30 - 07:00 1.50 DRILL PROD1 Cut & slip 65' drlg line. Serv & inspect drawworks. 07:00 - 11:00 4.00 DRILL PROD1 RIH. Precautionary wash & ream f/8740'-9196'. Hole looked good. 11:00 - 13:00 2.00 DRILL PROD1 Rotate & reciprocate while circ sweep around as before. Returns look good. Spot casing running pill. Pump dry job. Monitor well. 13:00 - 23:30 10.50 DRILL PROD1 Start LDDP. Intermittent tight spots f/9100'-8836' pulling 25k-45K over. Worked tight spot @ 8900' pulling 75k-90k over. Wiped down OK. Pull 30k coming back up. Pulled good f/8836'. Monitor well @ shoe. LD to BHA. 23:30 - 00:00 0.50 DRILL PROD1 PJSM. LD BHA. 2/1/2001 00:00 - 01:30 1.50 DRILL PROD1 Finish LD BHA and clear floor. 01:30 - 02:00 0.50 CASE COMP PJSM. Pull wear ring & set test plug. 02:00 - 03:00 1.00 CASE COMP Change top rams to 7". 03:00 - 03:30 0.50 CASE COMP Test door seals to 3500 psi-OK. RD test equipment. 03:30 - 04:00 0.50 CASE COMP Make dummy run w/7" mandrel hanger & landing jt. 04:00 - 05:30 1.50 CASE COMP RU casing tools. MU Franks fill-up tool. 05:30 - 06:00 0.50 CASE COMP PJSM w/crew on running casing. 06:00 - 10:30 4.50 CASE COMP PU & RIH w/7" casing to 9 5/8" shoe. 10:30 - 11:30 1.00 CASE COMP Circ casing volume. PU 119k; SO 92k. 595 psi @ 6 bpm. Spill Drill-OS-1:40 min. 11:30 - 18:30 7.00 CASE COMP Continue RIH @ 60'/min to minimize losses. Held PJSM @ crew change. Ran a total of 220 jts 7", 26#, L-80, BTC-Mod. 18:30 - 19:30 1.00 CASE COMP MU landing jt & hanger. Wash down & land in well head. RD Franks tool & MU cement head. 19:30 - 22:30 3.00 CEMT COMP Stage rate up slowly f/2 bpm @ 500 psi to 6 bpm @ 810 psi. Broke pipe free w/425k. Reciprocated w/PU: 280k & SO: 125k. CBU x 2. PJSM. Batch mix tail cement. Spill Drill-OS-l:10 min. 22:30 - 23:30 1.00 CEMT COMP Pumped cement as per program: 111 bbls (260 sxs) LiteCrete ~ 12 ppg; tailed w/52 bbls (244 sxs) GasBIok @ 15.8 ppg. Used top & bottom plugs. With lead cement 1/2 away. Hole started getting sticky. Landed casing. 23:30 - 00:00 0.50 CEMT COMP Start displacing cement w/8.9 ppg NaCI + 2% KCI @ 6 bpm. Printed: 2/26/2001 3:09:'15PM BP EXPLORATION Page 8 of lO Operations Summa Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG :Rig Name: NABORS 9ES Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 2/2/2001 00:00 - 01:00 1.00 CEMT COMP Finish displacement. Initial: 300 psi @ 6 bpm; Final: 1400 psi @ 6 bpm. Slowed rate to 3 bpm 10 bbls away. Bumped plug to 3500 psi @ 0045 2/2/01. Check floats-OK. FS @ 9186'; FC @ 9100'; & RA marker @ .6499'. 01:00 - 02:00 1.00 CEMT COMP LD landing jt & casing tools. 02:00 - 03:00 1.00 WHSUR COMP Install 9 5~8" x 7" packoff. Test to 5000 psi-OK. 03:00 - 04:00 1.00 BOPSUF COMP Set test plug. Change 7" rams to 3.5" x 6" variable. 04:00 - 05:30 1.50. BOPSUF COMP Finish changing top drive over f/5" to 4". 05:30 - 09:30 4.00 BOPSUF COMP Test BOPE to 250 / 3500 as per requirements. Witnessing waived by John Crisp-AOGCC Field Inspector. Pull test plug & set wear ring. 09:30 - 10:00 0.50 CEMT COMP Inject 5 bbls mud down annulus. 10:00 - 13:00 3.00 CLEAN COMP PJSM. MU ¢leanout BHA. 13:00 - 00:00 11.00 CLEAN COMP PJSM. PU 4" DP. (While PU 4", PJSM. Inject 130 bbls mud down 9 5/8" x 7" annulus @ 3 bpm w/800 psi. PJSM. RU Little Red hot oil. Freeze protect annulus w/60 bbls dead crude. Final: 1650 psi @ 2.5 bpm.) Fire Drill-OS-l:15 min. 2/3/2001 00:00 - 01:00 1.00 CLEAN COMP Continue PU 4" DP. Tag FC @ 9099'. 01:00 - 01:30 0.50 CLEAN COMP RU & reverse cir¢ DP volume x 2 @ 5 bpm w/600 psi. 01:30 - 14:30 13.00 CLEAN COMP Cir¢ sweep Hi-vis sweep around followed w/clean brine. Dump returns. Continue circ @ 2-3 bpm while filtering brine. Initial NTU: too dirty to read; Final NTU: 75. That's as good as we could get it. Spill Drill: OS-2 min. 14:30 - 15:30 1.00 CLEAN COMP RU & test 7" casing to 3500 psi f/30 min-OK. RD test equipment. 15:30 - 21:30 6.00 CLEAN COMP POH. LD jars. Stand back DC's & BHA. Clear floor. D1 Drill: OS-1:45 min. 21:30 - 22:00 0.50 EVAL COMP RU lubricator extension in Hydril. 22:00 - 23:30 1.50 EVAL COMP PJSM. RU SWS. Start RIH w/USIT. 2/4/2001 00:00 - 03:30 3.50 EVAL COMP Continue RIH w/SWS USIT tool. Correlate to SWS Density Neutron dated 1/27/01. Logged f/9090' - 4000'. Estimated TOC @ 4500'. Bond fairly poor to 4700'; improving to 5200'; increasing quality to 7300'; excellent to TD. Fire Drill: OS-1:45 mins. 03:30 - 06:30 3.00 PERF COMP Load pipe shed w/DPC guns. PJSM. MU guns. 06:30 - 10:00 3.50 PERF COMP RIH w/guns to 7385'. 10:00 - 16:30 6.50 PERF COMP RU SWS. RIH w/CCL/GR. Tie in to SWS Density Neutron dated 1/27/01. Correlate RA markers in casing & string. POH. Measure DP up 35'. LD 1 jr. RU SWS. RIH. Correlate. Adjust 1'to depth. POH. RD SWS. 16:30 - 17:30 1.00 PERF COMP PJSM. Fill all surface lines, choke, & gasbuster. Press DP to 3000 psi & hold 1 min. Bleed pressure. Guns fired in 5 mins. Perforated the following w/HES 4 5/8" carriers loaded 6 spf: 6920'--80' 7018'--50' :7070'--94' 7114'--24' 7162'--82' 7216'--66' 7280'--7302' 7325'--46'; 239' total loaded 17:30 - 18:00 0.50 PERF COMP Reverse ¢irc DP volume x 2 @ 5 bpm w/600 psi. Lost 8 bbls. 18:00 - 21:30 3.50 PERF COMP Monitor well. POOH w/DP. Shut down 2 stds f/guns. 21:30 - 22:30 1.00 PERF COMP PJSM. DP started flowing. Close TIW valve. Annulus percolating, but not flowing. Fluid level dropping slowly. MU top drive & close annular. Printed: 2/26/2001 3:09:15 PM BP EXPLORATION Page 9 of lO Operations Summary Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/4/2001 21:30 - 22:30 1.00 PERF COMP No pressures. D1 Drill: OS-40 sec. 22:30 - 00:00 1.50 PERF . COMP Circ through choke & gasbuster. No sign of any gas. Open annular & monitor well-dead. PJSM. 2/5/2001 00:00 - 04:00 4.00 PERF COMP PJSM. LD perf guns, breaking all connections. All shots fired. Clear floor. ~ 04:00 - 04:30 0.50 CLEAN COMP Service top drive. 04:30 - 05:00 0.50 CLEAN COMP MU cleanout BHA. 05:00 - 09:30 4.50 CLEAN COMP RIH. Run through perf interval slowly. No indication of any drag. Continue RIH. Washed 10' of fill to FC @ 9099'. D1 Drill: OS-1:50 min. 09:30 - 19:00 9.50 CLEAN COMP Circ sweep around @ 10 bpm w/1900 psi. Circ & filter. Initial: 215 NTU; Final: 37 NTU. 19:00 - 00:00 5.00 CLEAN COMP PJSM. Monitor well. POH above perfs. Start LD DP. Fire Drill: OS-1 min. 2/6/2001 00:00 - 03:30 3.50 CLEAN COMP Lay down 4" DP 03:30 - 04:30 1.00 CLEAN COMP Cut and Slip Drilling Line. 04:30 - 07:30 3.00 CLEAN COMP Complete laying down 4" DP, LID collars. 07:30 - 14:30 7.00 CLEAN COMP PJSM, Rig up HES slick line Lub. & BOP. Make two runs to 9099' with guage ring & Junk basket. Minimum trash recovered, some slag on first run< hence, run #2. PJSM, RID HES slick line. 14:30 - 15:30 1.00 CLEAN COMP Accident investigatio re. Dennis Nelson's slight puncture incident with rig creww, HES crew, T.P. and BP Co. Rep. 15:30 - 16:00 0.50 CLEAN COMP Complete RID HES Slick line. 16:00 - 00:00 8.00 RUNCOI~ COMP PJSM, R/U Tubing running equip., M/U and run 4.5" completion assembly as per program. Runnig slow as not to surge perfs. 70 Jts. of 191 Run. 2/7/2001 00:00 - 06:00 6.00 RUNCOI~ COMP Complete running 4.5" Completion String: 191 Jts. 12.6#, L-80, NSCT Tubing, 4 Baker pkrs, 5 GLM, 4 CMU, w/all ass¢. equip.. 06:00 - 13:30 7.50 RUNCOIt COMP PJSM R/U SWS Lubricator, Run CCL,GR & Correlate. RID Lub., Space out with Pup jr, M/U Hgr & land tubing. RILDS, R/U lub & re-run CCL -GR to verify correlation. WLEG set at 8736' RID SWS. ;13:30 - 16:00 2.50 RUNCOI~I COMP Spot 157 bbls. 8.9 # Brine treated w/Corexit corrosion inhibitor 16:00 - 17:00 1.00 RUNCOI~I COMP PJSM on setting Packers and Slickline. Drop ball rod for packer # 1. 17:00 - 18:00 1.00 RUNCOI~I COMP Pressure up on pkr # l to 3500 psi., bleed to 2000 psi. and pres. annulus to 3000 psi. tested OK. 18:00 - 00:00 6.00 RUNCOI~ COMP R/U HES Slickline w/Lubricator, Pull ball rod and RHC plug from . packer # 1 2/8/2001 00:00 - 07:00 7.00 RUNCOI~ COMP 'Set Packer # 2 @ 7061' and Packer # 3 @ 7201' as per program - No Problems. 07:00 - 09:00 2.00 RUNCOI~ COMP Drop ball-rod for Packer # 4 @ 8679'. Pressure to 4200 psi. Hold for 30 minute tubing test. Bleed tbg. to 2000 psi then pressure annulus to 4000 psi for 30 minutes to test top of packer # 1 @ 6853'. Bleed annulus pressure to 3000 psi. Bleed tubing pressure and shear RP. Do NOT retrieve ball rod nor pull RHC. 09:00 - 10:00 1.00 RUNCOI~I COMP Rig down HES & lubricator. 10:00 - 10:30 0.50 WHSUR COMP Set Two Way Check, test to 1000 psi via annulus. 10:30 - 12:00 1.50 WHSUR COMP Pull mouse hole, flow riser, air boots & clean top of Hydril. 12:00 - 16:30 4.50 BOPSUF~OTHR COMP PJSM Attempt to break out Hydril cap in order to change out damaged element. Unable to break out. 16:30 - 19:30 3.00 BOPSUF COMP Change out top and bottom pipe rams to 7". 19:30 - 00:00 4.50 BOPSUF COMP PJSM, Rig" Potato Masher" tool onto Hydril cap. Break cap and back out. Pull damaged element, clean interior, Install new element. Replace cap & Rig down" Potato Masher ". Function test Hydril. Printed: 2/26/2001 3:09:'15 PM BP EXPLORATION Page lo of 10 Operations Summar Report Legal Well Name: S-104 Common Well Name: S-104 Spud Date: 1/11/2001 Event Name: DRILL+COMPLETE Start: 1/10/2001 End: 2/9/2001 Contractor Name: NABORS Rig Release: 2/9/2001 Group: RIG Rig Name: NABORS 9ES Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/9/2001 00:00 - 03:30 3.50 BOPSUR COMP PJSM - N/D BOP Stack. 03:30 - 06:00 2.50 WHSUR COMP N/U Adaptor Flange & Tree, Test both to 5000 psi. 06:00 - 08:30 2.50 CHEM COMP Pull TWC, Reverse Circ. 85 bbls. diesel w/Little Red down annulus, shut in and allow equalization. 08:30 - 10:30 2.00 WHSUR COMP RID Hot Oiler and lines, Install BPV w/DSM and R/D DSM. 10:30 - 12:00 1.50 WHSUR COMP Blow down all lines and pumps after unloadig last of brine. Disconnect lines. RIG RELEASED AT 12:00 hrs. Printed: 2/26/2001 3:09:15 PM Well: S-104 Accept: 01/10/01 Field: Prudhoe Bay Spud: 01/11/01 APl: 50-029-22988-00 Release: 02/09/01 Permit: 200-196 Rig: Nabors 9ES Date POST-RIG WORK 03/13/01 Pull ball and rod at 8724' sim. Pull RHC body at 8727' sim. Drift tubing with 3.5" dummy gun. Tag bottom at 9106' sim. Rig down, move off. 03/26/01 Add Perforate 8810' to 8840' with 3-3/8", 6 spf, PJ. Put on Production. Note: This is a pre-produced injector. Plans are to convert it to an injector around the end of June 2001. North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad, Slot S-~04 S-~04 GYRO Surveyed: 27 ,January, '2001 DEFINITIVE SURVEY REPORT 3 February, 2001 Your Ref: APl 500292298800 Surface Coordinates: 5980849.97 N, 618930.01 E (70° 21' 22.6830" N, 149° 02' 02.8603" VI/) Kelly Bushing: 64.50ft above Mean Sea Level DRILLII~i6 El; I~ IRV I CE =, A Halliburton Company Survey Ref: svyf0731 SPerry-Sun Drilling Services Survey Report for S.104 GYRO Your Ref: APl 500292298800 Surveyed: 27 January, 200~ DE F NJT V North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -64.50 0.00 0.00 N 0.00 E 5980849.97 N 618930.01 E 109.00 0.250 133.000 44.50 109.00 0.16 S 0.17 E 5980849.81 N 618930.19 E 204.00 0.150 75.000 139.50 204.00 0.27 S 0.45 E 5980849.71 N 618930.46 E 298.00 0.500 12.000 233.50 298.00 0.16 N 0.65 E 5980850.14 N 618930.66 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.624° (12-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vedical Section is from Well and calculated along an Azimuth of 337.230° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 298.00ft., The Bottom Hole Displacement is 0.67ft., in the Direction of 76.026° (True). Dogleg Rate (°~'~OOft) Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 0.00 0.23 -0.22 0.22 -0.42 0.48 -0.10 Tolerable Gyro Survey tool program for S,104 GYRO From To Measured Vertical Measured Vertical Depth Depth Depth Depth fit) (ft) (ft) (ft) 0.00 0.00 298.00 298.00 Survey Tool Description Tolerable Gyro 3 February, 2001 - 1:07 Page 2 of 2 DrillQuest 2.00.06 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-104 S-104 Surveyed: 27 January, 2001 SURVEY REPORT March, 2001 Your Ref: AP1500292298800 Surface Coordinates: 5980849.97 N, 618930.01 E (70° 2~' 22.6830" N, Kelly Bushing: 64.50ft above Mean Sea Level ~49°02'02.8603-H0 m DRILLING SERVIC~E~ A Halliburton Company Survey Ref: svy'10732 North Slope Alaska Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) 298.00 0.500 12.000 233.50 298.00 335.79 0.550 6.362 271.29 335.79 424.21 2.270 6.498 359.68 424.18 517.19 3.630 6.335 452.53 517.03 609.25 5.620 358.228 544.29 608.79 635.61 726.95 818.64 908.62 994.81 701.33 8.980 353.440 794.35 12.720 356.360 889.11 16.440 357.099 983.50 18.710 357.431 1075.03 20.630 356.212 700.11 791.45 883.14 973.12 1059.31 1165.88 22.210 353.588 1079.38 1143.88 1259.09 23.950 353.041 1165.13 1229.63 1353.81 29.680 350.094 1249.63 1314.13 1385.89 30.760 349.560 1277.35 1341.85 1447.22 31.160 349.074 1329.94 1394.44 1542.79 32.450 351.208 1411.16 1475.66 1636.33 32.440 353.858 1490.11 1554.61 1730.00 34.150 354.784 1568.40 1632.90 1819.91 38.070 354.840 1641.02 1705.52 1915.25 41.080 354.155 1714.50 1779.00 Sperry-Sun Drilling Services Survey Report for S-104 Your Ref: AP1 500292298800 Surveyed: 27 January, 2001 PBU WOA S Pad 2009.74 44.100 354.180 1784.06 1848.56 2104.15 44.450 354.529 1851.65 1916.15 2136.57 46.700 354.501 1874.35 1938.85 2167.65 48.740 354.196 1895.25 1959.75 2196.85 49.510 354.613 1914.36 1978.86 2289.71 51.730 354.886 1973.27 2037.77 2383.72 52.900 355.423 2030.74 2095.24 2480.73 55.210 354.218 2087.69 2152.19 2570.20 54.850 354.013 2138.97 2203.47 2664.58 56.410 353.221 2192.25 2256.75 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 0.16 N 0.65 E 5980850.14 N 618930.66 E 0.50 N 0.70 E 5980850.48 N 618930.71 E 2.67 N 0.95 E 5980852.65 N 618930.92 E 7.42 N 1.48 E 5980857.41N 618931.37 E 14.82 N 1.66 E 5980864.82 N 618931.44 E 26.47 N 0.70 E 5980876.45 N 618930.29 E 43.91 N 0.78W 5980893.86 N 618928.54 E 67.72 N 2.12W 5980917.65 N 618926.82 E 96.19 N 3.47W 5980946.09 N 618925.01 E 126.95 N 5.20W 5980976.82 N 618922.80 E 159.98 N 8.17W 5981009.80 N 618919.30 E 196.27 N 12.43W 5981046.02 N 618914.46 E 238.49 N 18.80W 5981088.14 N 618907.43 E 254.39 N 21.65W 5981103.98 N 618904.32 E 285.39 N 27.50W 5981134.89 N 618897.98 E 335.01N 36.11W 5981184.36 N 618888.59 E 384.76 N 42.63W 5981234.00 N 618881.28 E 435.92 N 47.71W 5981285.08 N 618875.39 E 488.68 N 52.50W 5981337.76 N 618869.76 E 549.13 N 58.33W 5981398.11N 618862.97 E 612.74 N 64.83W 5981461.60 N 618855.46 E 678.33 N 71.31W 5981527.08 N 618847.94 E 701.37 N 73.53W 5981550.09 N 618845.36 E 724.26 N 75.79W 5981572.93 N 618842.73 E 746.23 N 77.94W 5981594.87 N 618840.23 E 817.70 N 84.51W 5981666.23 N 618832.53 E 891.83 N 90.79W 5981740.25 N 618825.07 E 970.04 N 97.89W 5981818.33 N 618816.73 E 1042.97 N 105.41W 5981891.13 N 618808.06 E 1120.38 N 114.07W 5981968.40 N 618798.16 E Dogleg Vertical Rate Section (°/'~ OOft) -0.10 0.19 0.19 1.95 2.09 1.46 6.27 2.27 13.02 3.71 24.14 4.06 40.79 3.93 63.26 2.41 90.04 2.14 119.07 2.03 150.68 1.88 185.79 6.21 227.18 3.47 242.94 0.77 273.79 1.79 322.88 1.52 371.27 1.90 420.41 4.36 470.91 3.19 528.91 3.20 590.08 0.45 653.06 6.94 675.17 6.60 697.15 2.85 718.24 2.40 786.68 1.32 857.47 2.58 932.33 0.44 1002.48 1.79 1077.22 Comment Tie on point AK-6 BP IFR-AK -- '1 March, 2001 - 9:53 Page 2 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-lO4 Your Ref: AP1 500292298800 Surveyed: 27 January, 200~ North Slope Alaska Measured Depth (ft) 2758.65 2852.43 2945.82 3039.64 3134.56 3229.50 3323.86 3417.51 3512.05 3605.22 3688.35 3780.51 3874.31 3968.79 4061.85 4154.82 4246.99 4342.05 4437.39 4531.72 Incl. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Northings Eastings (ft) (ft) 54.350 352.345 2245.69 2310.19 1197.18 N 123.79W 56.450 352.448 2298.94 2363.44 1273.69 N 134.00W 55.780 353.130 2351.01 2415.51 1350.61 N 143.74W 56.560 353.180 2403.24 2467.74 1427.98 N 153.02W 55.280 352.269 2456.43 2520.93 1505.97 N 162.98W 57.030 352.988 2509.30 2573.80 1584.16 N 173.09W 56.450 353.403 2561.05 2625.55 1662.51 N 182.44W 55.520 353.107 2613.44 2677.94 1739.60 N 191.55W 54.710 353.345 2667.51 2732.01 1816.61 N 200.70W 54.650 353.659 2721.38 2785.88 1892.14 N 209.30W 353.532 2770.11 2834.61 1959.06 N 216.82W 353.723 2825.07 2889.57 2032.59 N 225.03W 352.831 2880.37 2944.87 2107.83 N 233.90W 353.346 2934.79 2999.29 2184.50 N 243.19W 354.677 2987.63 3052.13 2260.68 N 251.18W 53.560 53.230 54.520 55.140 55.660 55.060 55.580 54.980 54.890 56.990 355.124 3040.48 3104.98 2336.87 N 257.98W 357.231 3092.93 3157.43 2412.49 N 263.03W 355.801 3147.07 3211.57 2490.47 N 267.78W 354.633 3201.85 3266.35 2568.23 N 274.28W 353.937 3254.67 3319.17 2645.99 N 282.07W 4625.35 55.970 353.966 3306.38 3370.88 2723.61 N 290.29W 4716.31 54.480 353.846 3358.26 3422.76 2797.90 N 298.22W 4810.39 53.690 354.144 3413.44 3477.94 2873.68 N 306.20W 4904.82 54.020 355.549 3469.14 3533.64 2949.62 N 313.04W 4997.95 54.300 356.287 3523.67 3588.17 3024.92 N 318.42W 5093.27 53.450 356.245 3579.87 3644.37 3101.75 N 323.43W 5185.90 52.820 353.389 3635.45 3699.95 3175.54 N 330.12W 5279.09 51.540 351.993 3692.59 3757.09 3248.56 N 339,47W 5372,07 49.090 350.054 3751.96 3816.46 3319.23 N 350,62W 5464.11 48.110 347.588 3812.83 3877.33 3386.95 N 363.99W Global Coordinates Northings Eastings (ft) (ft) 5982045.03 N 618787.23 E 5982121.37 N 618775.80 E 5982198.12 N 618764.85 E 5982275.35 N 618754.33 E 5982353.16 N 618743.15 E 5982431.19 N 618731.79 E 5982509.38 N 618721.20 E 5982586.31N 618710.86 E 5982663.16 N 618700.49 E 5982738.55 N 618690.69 E 5982805.34 N 618682.12 E 5982878.73 N 618672.74 E 5982953.82 N 618662.67 E 5983030.33 N 618652.17 E 5983106.38 N 618642.97 E 5983182.45 N 618634.96 E 5983257.98 N 618628.71E 5983335.88 N 618622.73 E 5983413.53 N 618614.99 E 5983491.15 N 618605.97 E 5983568.63 N 618596.51E 5983642.78 N 618587.40 E 5983718.42 N 618578.23 E 5983794.25 N 618570.18 E 5983869.46 N 618563.61 E 5983946.20 N 618557.38 E 5984019.87 N 618549.52 E 5984092.73 N 618539.00 E 5984163.21N 618526.74 E 5984230.71 N 618512.30 E Dogleg Rate (°/lOOft) 2.32 2.24 0.94 0.83 1.57 1.95 0.72 1.03 0.88 0.28 1.32 0.39 1.58 0.79 1.30 0.76 1.96 1.39 1.01 2.31 1.09 1.64 0.88 1.25 0.71 0.89 2.56 1.81 3.09 2.27 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 1151.79 1226.29 1300.98 1375.92 1451.68 1527.69 1603.55 1678.16 1752.71 1825.69 1890.30 1961.27 2034.08 2108.38 2181.71 2254.59 2326.27 2400.02 2474.24 2548.94 2623.70 2695.27 2768.23 2840.90 2912.42 2985.20 3055.83 3126.77 3196.25 3263.87 March, 2001. 9:53 Page 3 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-'i04 Your Ref: AP1500292298800 Surveyed: 27 January, 200'1 North Slope Alaska Measured Depth (ft) Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 5556.53 46.280 345.461 3875.63 3940.13 5649.20 42.840 344.073 3941.66 4006.16 5742.49 40.100 341.495 4011.56 4076.06 5836.28 39.400 342.911 4083.67 4148.17 5933.94 38.060 341.624 4159.85 4224.35 6027.46 37.390 341.828 4233.82 4298.32 6122.58 36.330 340.755 4309,93 4374.43 6213.91 35.210 335.982 4384.04 4448.54 6308.67 34.430 333.264 4461.84 4526.34 6400.55 33.220 329.166 4538.18 4602.68 6494.69 32.340 6587.55 32.280 6681.20 31.350 6772.68 30.520 6868.32 ,._29.550 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 3452.88 N 379.77W 5984296.39 N 618495.47 E 3515.61 N 396.83W 5984358.84 N 618477.42 E 3574.62 N 415.07W 5984417.55 N 618458.24 E 3631.72 N 433.40W 5984474.35 N 618439.00 E 3689.92 N 452.00W 5984532.24 N 618419.48 E 3744.25 N 469.95W 5984586.29 N 618400.68 E 3798,29 N 488.24W 5984640.03 N 618381.53 E 3847.90 N 507.88W 5984689.32 N 618361.10 E 3896.78 N 531.05W 5984737.83 N 618337.16 E 3941.59 N 555.64W 5984782,25 N 618311.86 E 325.715 4617.33 4681.83 3984.55 N 583.05W 320.829 4695.83 4760.33 4024.30 N 612.71W 316.390 4775.42 4839.92 4061.33 N 645.31W 308.758 4853.91 4918.41 4093.12 N 679.85W 302.233 4936.73 5001.23 4120.91 N 718.75W 6961.55 29.140 297.580 5018.01 5082.51 7054.69 29.640 292.198 5099.18 5163.68 7149.43 29.990 286.423 5181.40 5245.90 7245.07 30.010 279.599 5264.25 5328.75 7334.21 30.090 273.534 5341.42 5405.92 7425.10 29.370 272.828 5420.35 5484.85 7517.36 28.650 274.919 5501.04 5565.54 7610.43 28.160 274.674 5582.90 5647.40 7705.71 27.440 271.912 5667.19 5731.69 7798.76 26.640 272.570 5750.06 5814.56 5984824.76 N 618283.78 E 5984864,03 N_ 618253.49 E 5984900.54 N 618220.30 E 5984931.78 N 618185.26 E 5984958.95 N 618145.93 E 4143.68 N 758.32W 5984981.09 N 618106.00 E 4162.88 N 799.75W 5984999.63 N 618064.27 E 4178.43 N 844,16W 5985014.47 N 618019.62 E 4189.18 N 890.69W 5985024.48 N 617972.93 E 4194.28 N 934.98W 5985028.88 N- 617928.56 E 4196.78 N 979.98W 5985030.67 N 617883.52 E 4199.80 N 1024.62W 5985032.97 N 617838.84 E 4203.50 N 1068;74W 5985035.97 N 617794.67 E 4206.06 N 1113.09W 5985037.83 N 617750.29 E 4207.71N 1155.36W 5985038.81N 617708.00 E 7892.89 25.530 276.399 5834.61 5899.11 7986.44 24.380 281.707 5919.44 5983.94 8079.99 22.720 278.936 6005.19 6069.69 8173.13 19.720 272.696 6092.02 6156.52 8268.13 16.690 265.020 6182.27 6246.77 4210.92 N 1196.60W 5985041.36 N 617666.71E 4217.09 N 1235.55W 5985046.91 N 617627.67 E 4223.81 N 1272.30W 5985053.05 N 617590.81 E 4227.35 N 1305.78W 5985056.05 N 617557.28 E 4226.91 N 1335.39W 5985055.15 N 617527.68 E 2.60 3.86 3.46 1.22 1.60 0.73 1.30 3.29 1.83 2.81 2.19 2.81 2.69 4.38 3.56 2.48 2.88 3.05 3.57 3.41 0.88 1.35 0.54 1.55 0.92 2.14 2.69 2.13 4.03 4.06 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 3330.77 3395.21 3456.68 3516.43 3577.29 3634.33 3691.24 3744.58 3798.62 3849.46 3899.67 3947.81 3994.57 4037.25 4077.93 4114.24 4147.98 4179.51 4207.43 4229.27 4249.00 4269.05 4289.54 4309.07 4326.95 4345.87 4366.63 4387.06 4403.27 4414.33 March, 200~ - 9:53 Page 4 of 6 DriliQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-104 Your Ref: AP1 500292298800 Surveyed: 27 January, 200f North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 8363.00 15.540 264.423 6273.41 6337.91 4224.50 N 1361.61W 8457.69 13.690 262.908 6365.03 6429.53 4221.88 N 1385.36W 8550.22 9.650 257.932 6455.63 6520.13 4218.91 N 1403.82W 8645.49 8.510 256.707 6549.71 6614.21 4215.62 N 1418.49W 8702.18 8.090 256.222 6605.80 6670.30 4213.70 N 1426.44W Global Coordinates Northings Eastings (ft) (ft) 5985052.32 N 617501.50 E 5985049.32 N 617477.80 E 5985046.06 N 617459.39 E 5985042.53 N 617444.78 E 5985040.49 N 617436.85 E 8739.10 7.720 257.755 6642.37 6706.87 4212.56 N 1431.39W 8832.48 7.820 259.130 6734.89 6799.39 4210.03 N 1443.76W 8926.44 7.910 257.869 6827.97 6892.47 4207.46 N 1456.35W 9018.72 8.460 260.595 6919.31 6983.81 4205.02 N 1469.26W 9114.25 8.970 261.377 7013.74 7078.24 4202.76 N 1483.56W 5985039.27 N 617431.92 E 5985036.55 N 617419.60 E 5985033.78 N 617407.04 E 5985031.13 N 617394.18 E 5985028.64 N 617379.92 E 9151.07 9.200 261.707 7050.10 7114.60 4201.90 N 1489.31W 9196.00 9.200 261.707 7094.45 7158.95 4200.86 N 1496.41W 5985027.70 N 617374.18 E 5985026.55 N 617367.09 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.624° (12-Jan-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 337.230° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9196.00ff., The Bottom Hole Displacement is 4459.43ft., in the Direction of 340.393° (True). Dogleg Rate (°/100ft) 1.22 1.99 4.50 1.21 0.75 1.15 0.23 0.21 0.73 0.55 0.64 0.00 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 4422.25 4429.03 4433.43 4436.08 4437.39 4438.25 4440.70 4443.22 4445.96 4449.40 4450.84 4452.64 Projected Survey March, 200~ - 9:53 Page 5 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-'104 Your Ref: AP1500292298800 Surveyed: 27 January, 2001 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 298.00 298.00 0.16 N 0.65 E 9196.00 7158.95 4200.86 N 1496.41 W Comment Tie on point Projected Survey Survey tool program for S-104 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 298.00 298.00 298.00 298.00 9196.00 7158.95 Survey Tool Description Tolerable Gyro (S-104 GYRO) AK-6 BP_IFR-AK (S-104) March, 2001 - 9:53 Page 6 of 6 DrillQuest 2.00.06 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad, Slot S-~04 S.~04 MWD Surveyed: 27 January, 2001 S UR VEY REPORT 3 February, 2001 Your Ref: APl - 500292298800 Surface Coordinates: 5980849.97' N, 6~8930.0~ E (70° 2'/' 22.6830" N; ~49° 02' 02.8603" VI/) Kelly Bushing: 64.50ft above Mean Sea Level D R ! L.. !-- I I~11~ 5ERVICE~ A Halliburton Company Survey Ref: svyf0730 Sperry-Sun Drilling erwces Survey Report for S-104 MWD Your Ref: AP1 - 500292298800 Surveyed: 27 January, 2001 North Slope Alaska Measured Depth Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 298.00 0.500 12.000 233.50 298.00 335.79 0.550 6.500 271.29 335.79 424.21 2.270 6.660 359.68 424.18 517.19 3.630 6.330 452.53 517.03 609.25 5.620 358.210 544.29 608.79 635.61 726.95 818.64 908.62 994.81 701.33 8.980 353.560 794.35 12.720 356.450 889.11 16.440 357.140 983.50 18.710 357.440 1075.03 20.630 356.420 0.16 N 0.65 E 0.50 N 0.70 E 2.66 N 0.96 E 7.42 N 1.49 E 14.82 N 1.67 E 700.11 26.47 N 0.73 E 791.45 43.91N 0.72W 883.14 67.73 N 2.04W 973.12 96.20 N 3.38W 1059.31 126.96 N 5.04W 1165.88 22.210 353.720 1079.38 1143.88 1259.09 23.950 353.010 1165.13 1229.63 1353.81 29.680 350.050 1249.63 1314.13 1385.89 30.760 349.670 1277.35 1341.85 1447.22 31.160 349.150 1329.94 1394.44 1542.79 32.450 351.420 1411.16 1475.66 1636.33 32.440 353.910 1490.11 1554.61 1730.00 34.150 354.630 1568.40 1632.90 1819.91 38.070 354.770 1641.02 1705.52 1915.25 41.080 354.260 1714.50 1779.00 2009.74 44.100 354.320 2104.15 44.450 354.610 2136.57 46.700 354.620 2167.65 48.740 354.280 2196.85 49.510 354.720 2289.71 51.730 355.060 2383.72 52.900 355.600 2480.73 55.210 354.390 2570.20 54.850 354.270 2664.58 56.410 353.610 160.00 N 7.92W 196.29 N 12.15W 238.51 N 18.55W 254.40 N 21.39W 285.42 N 27.19W 335.06 N 35.67W 384.82 N 42.08W 435.98 N 47.20W 488.73 N 52.09W 549.19 N 57o91W 1784.06 1851.65 1874.35 1895.25 1914.36 1973.27 2030.74 2087.69 2138.97 2192.25 1848.56 612.81N 64.27W 1916.15 678.41N 70.62W 1938.85 701.46 N 72.80W 1959.75 724.34 N 75.02W 1978.86 746.32 N 77.14W 2037.77 817.81 N 83.53W' 2095.24 891.96 N 89.58W 2152.19 970.19 N 96.44W 2203.47 1043,14 N 103.69W 2256.75 1120.61N 111.92W 5980850.14 N 618930.66 E 5980850.48 N 618930.71 E 5980852.65 N 618930.92 E 5980857.41N 618931.39 E 5980864.82 N 618931.45 E 5980876.45 N 618930.32 E 5980893.87 N 618928.59 E 5980917.66 N 618926.90 E 5980946.10 N 618925.10 E 5980976.83 N 618922.95 E 5981009.83 N 618919.55 E 5981046.05 N 618914.74 E 5981088.16 N 618907.68 E 5981104.00 N 618904.58 E 5981134.92 N 618898.29 E 5981184.42 N 618889.02 E 5981234.07 N 618881.83 E 5981285.15 N 618875.89 E 5981337.81N 618870.16 E 5981398.17 N 618863.39 E 5981461.68 N 618856.02 E 5981527.17 N 618848.62 E 5981550.18 N 618846.09 E 5981573.03 N 618843.50 E 5981594.97 N 618841.03 E 5981666.35 N 618833.51E 5981740.39 N 618826.28 E 5981818.50 N 618818.18 E 5981891.34N 618809.77 E 5981968.66 N 618800.32 E Dogleg Rate (°/100ft) Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment -0.10 Tie On Point MWD Magnetic 0.19 0.19 1.95 2.09 1.46 6.26 2.27 13.02 3.70 24.13 4.06 40.77 3.93 63.24 2.41 90.01 2.13 119.01 2.05 150.60 1.89 185.70 6.21 227.10 3.42 242.86 0.78 273.70 1.84 322.75 1,43 371.11 1.87 420.27 4.36 47O.80 3.18 528.80 3.20 589.92 0.43 652.87 6.94 674.96 6.61 696.93 2.87 718.01 2.41 786.40 1.32 857.11 2.59 931.90 O.42 1001.98 1.75 1076,59 3 February, 2001- 1:06 Page 2 of 6 DrillOuest 2.00.06 Sperry-Sun DnTling Services Survey Report for S-f04 MWD Your Ref: AP1 - 500292298800 Surveyed: 27 January, 2001 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2758.65 54.350 352.360 2245.69 2310.19 2852.43 56.450 352.360 2298.94 2363.44 2945.82 55.780 353.080 2351.01 2415.51 3039.64 56.560 353,090 2403.24 2467.74 3134.56 55.280 352.220 2456.43 2520.93 3229.50 57.030 352,950 2509.30 2573.80 3323.86 56.450 353,320 2561,05 2625.55 3417,51 55.520 353,320 2613.44 2677.94 3512.05 54.710 353,290 2667.51 2732.01 3605.22 54.650 353,620 2721.38 2785.88 3688.35 53.560 353.700 2770.11 2834.61 3780,51 53.230 353,800 2825.07 2889.57 3874.31 54.520 352.940 2880.37 2944.87 3968.79 55.140 353.430 2934.79 2999.29 4061.85 55,660 354.720 2987.63 3052.13 4154.82 55.060 355.200 3040.48 3104.98 4246.99 55.580 357.320 3092.93 3157.43 4342.05 54,980 355,810 3147.07 3211.57 4437.39 54.890 354,710 3201.85 3266.35 4531.72 56.990 353.980 3254.67 3319.17 4625.35 55.970 354.100 3306.38 3370.88 4716.31 54.480 354.050 3358.26 3422.76 4810,39 53.690 354.350 3413.44 3477.94 4904.82 54.020 355.570 3469.14 3533.64 4997,95 54.300 356.380 3523.67 3588.17 5093.27 53.450 356.220 3579.87 3644.37 5185.90 52.820 353,390 3635.45 3699.95 5279.09 51.540 352.000 3692.59 3757.09 5372.07 49.090 350.100 3751.96 3816.46 5464.11 48.110 347.630 3812.83 3877.33 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1197.44N 121.36W 5982045.33 N 618789.66 E 1273.94N 131.62W 5982121.66 N 618778.18 E 1350.84N 141.45W 5982198.40 N 618767.14 E 1428.21 N 150.83W 5982275.61 N 618756.53 E 1506.18 N 160.88W 5982353.41 N 618745.24 E 1584,37 N 171.05W 5982431.43 N 618733.83 E 1662.71N 180.48W 5982509.60 N 618723.16 E 1739.80 N 189.51W 5982586.55 N 618712.90 E 1816.83 N 198.55W 5982663.42 N 618702,64 E 1892.35 N 207.21W 5982738.79 N 618692.78 E 1959.28 N 214.65W 5982805.60 N 618684.28 E 2032.82 N 222.71W 5982879.00 N 618675.06 E 2108.08 N 231.46W 5982954.11 N 618665.11 E 2184.77 N 240.62W 5983030.64N 618654.73 E 2260.96N 248.52W 5983106.69 N 618645.62 E 2337.15 N 255.25W 5983182.77 N 618637.69 E 2412.78 N 260.18W 5983258.31N 618631.55 E 2490.77 N 264.86W 5983336.22 N 618625.64 E 2568.53 N 271.31W 5983413.87 N 618617.96 E 2646.29 N 279.02W 5983491.50 N 618609.02 E 2723.93 N 287.12W 5983569,00 N 618599.68 E 2798.24 N 294.83W 5983643.18 N 618590,79 E 2874.05 N 302.53W 5983718.85 N 618581.88 E 2950.00 N 309.23W 5983794.69 N 618573.98 E 3025.31 N 314.53W 5983869.91 N 618567.49 E 3102.15 N 319.50W 5983946.65 N 618561.30 E 3175.94N 326.20W 5984020.33 N 618553.43 E 3248.95 N 335.55W 5984093.18 N 618542.92 E 3319.63 N 346.66W 5984163.67 N 618530.69 E 3387.36 N 359.98W 5984231.19 N 618516.30 E Dogleg Rate (°/100ft) 2.45 2.24 0.96 0.83 1.55 1.95 0.70 0.99 0.86 0.30 1.31 0.37 1.56 0.78 1.27 0.77 1.97 1.45 0.95 2.32 1.09 1.64 0.88 1.10 0.77 0.90 2.54 1.81 3.07 2.28 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 1151.08 1225.60 1300.31 1375.28 1451.06 1527.09 1602.98 1677.56 1752,08 1825.07 1889.66 1960.59 2033.37 2107.63 2180.94 2253.79 2325.44 2399.16 2473.36 2548.05 2622.77 2694.28 2767.15 2839.78 2911.27 2984.04 3054.67 , 3125.62 3195,08 3262.69 3 February, 2001 - '1:06 Page 3 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-lO4 MWD Your Reft AP1 - 500292298800 Surveyed: 27 January, 2001 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 5556.53 46.280 345.530 3875.63 3940.13 5649.20 42.840 344.180 3941.65 4006.15 5742.49 40.100 341.670 4011.56 4076.06 5836.28 39.400 343.260 4083.67 4148.17 5933.94 38.060 341.990 4159.85 4224.35 6027.46 37.390 342.140 4233.82 4298.32 6122.58 36.330 340.950 4309.93 4374.43 6213.91 35.210 336.250 4384.04 4448.54 6308.67 34.430 333.680 4461.84 4526.34 6400.55 33.220 329.660 4538.18 4602.68 6494.69 32.340 326.100 4617.33 4681.83 6587.55 32.280 321.090 4695.83 4760.33 6681.20 31.350 316.570 4775.42 4839.92 6772.68 30.520 309.630 4853.91 4918.41 6868.32 29.550 302.850 4936.73 5001.23 6961,55 29.140 298.250 5018.01 5082.51 7054.69 29.640 292.680 5099.18 5163.68 7149.43 29.990 287.020 5181.39 5245.89 7245.07 30.010 280.410 5264.24 5328.74 7334.21 30.090 274.120 5341.42 5405.92 7425.10 29.370 273.410 5420.35 5484.85 7517.36 28.650 275.200 5501.03 5585.53 7610.43 28.160 274.160 5582.90 5647.40 7705.71 27.440 272.740 5667.18 5731.68 7798.76 26.640 272.770 5750.06 5814,56 7892.89 25,530 275.370 5834.60 5899.10 7986.44 24.380 281.530 5919.43 5983.93 8079.99 22,720 278.700 6005.19 6069.69 8173.13 19.720 271.600 6092.02 6156.52 8268.13 16,690 263.640 6182.27 6246.77 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Easfings (ft) (ft) 3453.31 N 375.70W 5984296.88 N 618499.53 E 3516.06N 392.66W 5984359.36 N 618481.58 E 3575.12 N 410.76W 5984418.11N 618462.54 E 3632.30 N 428.83W 5984475.00 N 618443.56 E 3690.61 N 447.07W 5984533.01 N 618424.41 E 3745.05 N 464.69W 5984587.17 N 618405.92 E 3799.17 N 482.74W 5984641.00 N 618387.01 E 3848.85 N 502.18W 5984690.37 N 618366.79 E 3897.87 N 525.06W 5984739.02 N 618343.13 E 3942.88 N 549.30W 5984783.64N 618318.18 E 3986.04N 576.37W 5984826.36 N 618290.43 E 4025.96N 605.80W 5984865.81 N 618260.37 E 4063.12 N 638.26W 5984902.44 N 618227.32 E 4095.23 N 672.53W 5984934.00 N 618192.55 E 4123.52 N 711.05W 5984961.68 N 618153.58 E 4146.74 N 750.37W 5984984.27 N 618113.90 E 4166.35 N 791.60W 5985003.23 N 618072.36 E 4182.32 N 835.87W 5985018.49 N 618027.85 E 4193.64N 882.26W 5985029.08 N 617981.28 E 4199.28 N 926.48W 5985034.01 N 617936.97 E 4202.24 N 971.46W 5985036.26 N 617891.96 E 4205.59 N 1016.07W 5985038.90 N 617847.30 E 4209.21 N 1060.20W 5985041.81 N 617803.12 E 4211.89 N 1104.55W 5985043.79 N 617758.73 E 4213.92 N 1146.80W 5985045.15 N 617716.45 E 4216.84N 1188.08W 5985047.41 N 617675.14 E 4222.58N 1227.07W 5985052.54N 617636.05 E 4229.18 N 1263.85W 5985058.55 N 617599.17 E 4232.34N 1297.36W 5985061.18 N 617565.63 E 4231.27 N 1326.95W 5985059.64 N 617536.06 E Dogleg Rate (°/100ft) 2.59 3.85 3.43 1.32 1.60 0.72 1.34 3.25 1.75 2.77 2.25 2.88 2.73 4.00 3.69 2.46 2.98 2.99 3.45 3.53 0.88 1.22 0.75 1.03 0.86 1.69 3.O4 2.15 4.24 4.12 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 3329.58 3394.01 3455.47 3515.19 3576.01 3633.03 3689.93 3743.26 3797.31 3848.20 3898.47 3946.67 3993.49 4O36.36 4077.36 4113.98 4148.03 4179.88 4208.28 4230.59 4250.73 4271.08 4291.50 4311.13 4329.36 4348.03 4368.42 · 4388.73 4404.61 4415.09 3 February, 200f - 1:06 Page 4 of 6 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for S-f04 MWD Your Reft APl - 500292298800 Surveyed: 27 January, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8363.00 15.540 263.820 6273.41 6337.91 4228.40 N 1353.12 W 5985056.35 N 617509.93 E 8457.69 13.690 263.100 6365.03 6429.53 4225.68 N 1376.86 W 5985053.26 N 617486.24 E 8550.22 9.650 258.260 6455.63 6520.13 4222.79 N 1395.33 W 5985050.08 N 617467.82 E 8645.49 8.510 257.100 6549.70 6614.20 4219.59 N 1410,02 W 5985046.64 N 617453.18 E 8702.18 8.090 256.400 6605.80 6670.30 4217.72 N 1417.98 W 5985044.64 N 617445.24 E 8739.10 7.720 257,440 6642.37 6706.87 4216.57 N 1422.93 W 5985043.41 N 617440.32 E 8832.48 7.820 258.670 6734.89 6799.39 4213.95 N 1435.28 W 5985040.61 N 617428.01 E 8926.44 7.910 258,100 6827.97 6892.47 4211.37 N 1447.87 W 5985037.82 N 617415.46 E 9018.72 8.460 260.870 6919.31 6983.81 4208.98 N 1460.79 W 5985035.23 N 617402.58 E 9114.25 8.970 261.550 7013.74 7078.24 4206.77 N 1475.09 W 5985032.79 N 617388.31 E 9151.07 9.200 261.890 7050.09 7114.59 4205.93 N 1480.85W 5985031.86 N 617382.58 E 9196.00 9.200 261.890 7094.45 7158.95 4204.92 N 1487.96W 5985030.74 N 617375.48 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.625° (12-Jan-01) The Dogleg Severity is in Degrees per 100 feet. VertiCal Section is from Well and calculated along an Azimuth of 337.230° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9196.00ft., The Bottom Hole Displacement is 4460.42ft., in the Direction of 340.513° (True). Dogleg Rate (°/'~OOft) 1.21 1.96 4.49 1.21 0.76 1.07 0.21 0.13 0.73 0.54 0.64 0.00 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 4422.56 4429.25 4433.73 4436.46 4437.82 4438.67 4441.04 4443.53 4446.33 4449.83 4451.28 4453.10 Projected Survey DrillQuest 2.00.06 3 February, 200f - 1:06 Page 5 of 6 Sperry-Sun Drilling Services Survey Report for S-f04 MWD Your Ref: APl - 500292298800 Surveyed: 27 January, 2001 North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 298.00 298.00 0.16 N 0.65 E 9196.00 7158.95 4204.92 N 1487.96 W Comment Tie On Point Projected Survey Survey tool program for S-~04 MI/VD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 298.00 298.00 298.00 298.00 9196.00 7158.95 Survey Tool Description Tolerable Gyro (S-104 GYRO) MWD Magnetic (S-104 MWD) 3 February, 2001 - ~:06 Page 6 of 6 DrillQuest 2.00.06 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. ~ Well · S-104 ~,0~-- I ~(~ Field · Westend Location : Alaska r. ana~ ~£TH~LEIJN SJ;R'VI££S CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi ft(-1) microns ~llcm3 1 8778.6 800 14.40 .702 .750 4.41 7.05E+11 1.55E+03 2.719 2 8779.6 800 14.64 .201 .248 16.42 6.31E+12 3.89E+03 2.692 3 8781.6 800 15.40 .363 .421 10.72 4.68E+12 5.24E+03 2.729 4V 8782.2 800 14.83 .026 .050 76.73 1.48E+13 1.13E+03 2.704 4 8782.6 800 16.04 .379 .465 15.03 2.60E+12 3.05E+03 2.710 5V 8783.2 800 8.98 .006 .012 99.28 2.70E+13 4.51E+02 3.177 5 8783.7 800 9.05 .006 .017 158.89 2.04E+14 3.52E+03 2.975 6 8785.6 800 14.69 .030 .054 61.71 2.79E+13 2.51E+03 2.760 7V 8786.5 800 17.60 .052 .102 72.01 5.70E+12 8.91E+02 2.881 7 8786.7 800 17.99 .166 .274 45.31 9.32E+11 4.75E+02 2.889 8 8787.8 800 22.53 1.58 2.06 18.41 8.88E+10 4.45E+02 2.904 9 8788.3 800 20.10 1.29 1.61 15.19 2.96E+11 1.24E+03 2.714 10 8789.8 800 17.88 1.04 1.36 19.06 2.19E+11 7.38E+02 2.847 11V 8790.2 800 19.07 .838 1.16 24.32 2.38E+11 6.45E+02 2.858 11 8790.5 800 19.92 5.27 6.14 9.36 1.08E+10 1.85E+02 2.935 12 8791.6 800 22.70 2.66 3.48 18.06 2.12E+10 1.82E+02 3.001 13 8792.6 800 23.45 4.41 5.42 13.01 6.37E+09 9.09 E+O 1 2.906 14V 8793.2 800 21.55 1.78 2.32 18.29 5.16E+10 2.97E+02 2.835 14 8793.6 800 26.31 12.5 14.6 9.20 8.87E+08 3.59E+01 2.962 15 8794.4 800 22.24 5.67 6.86 11.80 2.77E+09 5.08E+01 2.880 16 8795.3 800 20.83 11.8 13.7 8.92 1.18E+09 4.47E+01 2.983 16V 8795.8 800 23.75 20.7 23.7 7.59 4.74E+08 3.17E+01 2.991 17 8796.3 800 24.56 22.6 26.1 7.95 3.81E+08 2.79E+01 2.961 18 8797.2 800 16.97 2.07 2.68 17.63 2.28E+ 10 1.52 E+02 2.861 19 8801.4 800 21.59 50.0 53.9 3.94 8.49E+07 1.37E+01 2.686 PRELIMINARY REPORT Page '1 CORE LABORATORIE$, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location : Alaska ~n~ CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi ft(-1) microns ~llcm3 20 8802.5 800 9.72 .038 .055 35.88 7.07E+12 8.67E+02 2.835 21 8803.5 800 25.00 317 327 1.44 8.71E+06 8.94E+00 2.829 22 8804.6 800 21.48 74.0 79.3 3.47 4.10E+07 9.82E+00 2.687 23V 8805.3 800 20.69 15.7 18.1 7.90 3.94E+08 2.01E+01 2.693 23 8805.5 800 20.26 29.6 32.9 5.67 1.12E+08 1.07E+01 2.685 24 8806.5 800 21.49 54.0 58.6 4.28 6.19E+07 1.08E+01 2.685 25 8807.5 800 19.38 13.4 15.6 8.44 3.85E+08 1.68E+01 2.672 26V 8808.1 800 19.12 3.35 4.27 15.79 3.21E+09 3.48E+01 2.670 26 8808.5 800 19.40 13.7 15.9 8.46 3.61E+08 1.59E+01 2.688 27 8809.5 800 20.61 26.5 29.7 6.30 1.40E+08 1.19E+01 2.697 28 8810.4 800 22.02 33.0 36.9 6.00 1.07E+08 1.13E+01 2.718 29V 8811.3 800 20.56 15.1 17.4 8.34 4.09E+08 1.97E+01 2.708 29 8811.6 800 19.90 24.3 27.4 6.46 1.46E+08 1.14E+01 2.713 30 8812.5 800 21.45 49.1 53.6 4.47 8.81E+07 1.39E+01 2.729 31 8813.6 800 21.27 49.1 53.5 4.42 7.76E+07 1.22E+01 2.733 32V 8814.2 800 21.79 33.8 37.3 5.25 1.70E+08 1.84E+01 2.750 32 8814.5 800 22.01 73.7 79.0 3.45 6.09E+07 1.44E+01 2.736 33 8815.5 800 23.00 143 150 2.26 2.44E+07 1.12E+01 2.721 34 8825.5 800 19.06 10.6 12.4 9.53 3.96E+08 1.34E+01 2.667 35V 8826.1 800 18.78 2.89 3.61 14.50 9.13E+09 8.44E+01 2.651 35 8826.5 800 19.11 12.8 14.9 8.89 2.79E+08 1.14E+01 2.652 36 8827.7 800 5.20 .001 .002 181.97 2.29E+16 4.27 E+04 2.714 37 8828.5 800 18.53 8.16 9.76 10.82 6.81E+08 1.78E+01 2.649 38V 8829.1 800 18.70 2.92 3.73 16.21 9.48E+09 8.84E+01 2.655 38 8829.6 800 19.77 11.8 13.9 9.36 3.65E+08 1.38E+01 2.658 39 8830.5 800 19.78 10.3 12.1 9.68 4.43E+08 1.46E+01 2.662 PRELIMINARY REPORT Page 2 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location : Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi ft(-1) microns glcm3 40 8832.5 800 20.35 8.08 9.73 11.20 6.34E+08 1.65E+01 2.663 41V 8832.7 800 19.65 3.52 4.46 15.47 3.11E+09 3.50E+01 2.664 41 8833.5 800 19.56 7.58 9.13 11.22 6.70E+08 1.63E+01 2.657 42 8834.6 800 19.53 9.56 11.3 9.94 5.42E+08 1.67E+01 2.672 43V 8835.1 800 19.05 2.47 3.14 15.97 1.53E+10 1.22E+02 2.673 43 8835.5 800 19.93 9.04 10.7 10.05 5.86E+08 1.71E+01 2.672 44 8836.5 800 20.68 13.4 15.5 8.39 3.06E+08 1.33E+01 2.675 45 8837.5 800 19.99 10.4 12.2 9.36 5.74E+08 1.93E+01 2.671 46V 8838.1 800 19.72 2.66 3.38 15.89 1.56E+10 1.34E+02 2.669 46 8838.5 800 19.53 5.51 6.73 12.36 1.27E+09 2.26E+01 2.687 47 8839.5 800 20.28 11.3 13.2 8.91 3.84E+08 1.41E+01 2.656 48 8840.5 800 16.33 .756 1.06 25.35 3.22E+11 7.88E+02 2.657 49V 8841.1 800 18.25 .453 .671 31.54 4.93E+ 11 7.23E+02 2.658 49 8841.6 800 17.36 1.31 1.76 20.70 6.57E+10 2.79E+02 2.655 50 8842.5 800 16.07 .446 .660 31.43 5.56E+11 8.04E+02 2.749 50V 8842.6 800 15.98 .116 .201 51.81 1.75E+12 6.61E+02 2.707 51 8843.5 800 14.99 .350 .477 24.19 9.19E+12 1.01E+04 2.676 52V 8844.1 800 17.03 .336 .516 35.95 9.66E+11 1.02E+03 2.629 52 8844.5 800 17.16 1.43 1.94 21.57 4.92E+10 2.24E+02 2.636 53 8845.5 800 16.69 1.15 1.56 21.80 9.22E+10 3.38E+02 2.642 54 8846.5 800 19.37 6.53 7.91 11.70 6.11E+08 1.28E+01 2.638 55V 8847.1 800 19.65 3.07 3.83 14.52 2.00E+10 1.96E+02 2.644 55 8847.5 800 20.85 10.6 12.4 9.31 4.61E+08 1.57E+01 2.642 56 8848.5 800 19.56 6.54 7.95 11.98 9.62E+08 2.02E+01 2.635 57 8849.5 800 20.02 13.1 15.2 8.53 2.69E+08 1.14E+01 2.641 PRELIMINARY REPORT Page 3 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location : Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi fi(-1) microns glcm3 58V 8850.1 800 19.60 2.53 3.31 18.07 1.40E+10 1.15E+02 2.671 58 8850.4 800 20.24 10.9 12.9 9.59 4.62 E+08 1,63E+01 2.667 59 8851.5 800 19.78 12.7 14.7 8.42 4.28E+08 1.75E+01 2.656 60 8852.5 800 18.64 10.4 12.1 8.97 5.35E+08 1.79E+01 2.651 61V 8853.5 800 19.99 2.81 3.57 15.71 1.40E+10 1.25E+02 2.650 61 8853.5 800 19.84 9.24 10.9 10.03 5.99E+08 1.77E+01 2.648 62 8854.5 800 20.08 12.4 14.6 9.28 3.90E+08 1.56E+01 2.639 63 8855.5 800 16.27 .992 1.36 23.27 1.49E+11 4,67E+02 2.636 64 8856.5 800 16.61 1.80 2.31 16.98 5.27E+10 3.01E+02 2.645 65 8857.5 800 16.59 2.19 2.73 14.58 4.61E+10 3,20E+02 2.660 66 8858.5 800 14.94 .120 .204 50.13 1.52E+12 5.57E+02 2.944 67V 8859.5 800 14.40 .045 .100 91.72 5.98E+12 8,12E+02 2.643 67 8859.5 800 14.14 .618 .643 2.55 1.94E+ 13 3,75E+04 2.642 68 8860.5 800 14.77 .219 .342 38.50 5.75E+11 4.08E+02 2.641 69 8861.5 800 16.85 .840 1.20 26.63 1.41E+11 3.82E+02 2.637 70 8862.5 800 17.52 1.84 2.39 18.09 3.10E+10 1.84E+02 2.639 71V 8863.5 800 18.88 2.24 2,87 16.56 2.95E+10 2.14E+02 2.631 71 8863.6 800 18.48 4.59 5.61 12.55 1.94 E+09 2.89E+01 2.666 72 8864.5 800 19.76 9.33 10.9 9.24 5.29 E+08 1.60E+01 2.646 73 8865.5 800 19.57 6.56 7.85 10.94 1.13E+09 2.41E+01 2.675 74 8866.5 800 21.42 25.3 28.4 6.17 8.88E+07 7.28E+00 2.642 75 8867.5 800 20.31 11.7 13.7 8.95 4.53E+08 1.72E+01 2.632 76V 8868.5 800 19.17 2.22 2.85 16.86 2.29E+10 1.64E+02 2.627 76 8868.5 800 19.42 8.75 10.4 10.13 6.13E+08 1.74E+01 2.638 77 8869.5 800 17.14 2.02 2.62 17.87 3.27E+10 2.09E+02 2.627 PRELIMINARY REPORT Page 4 CORE LABORATORIES, INC. HO US TON A D VA NCED TECHNOL 0 G Y CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location · Alaska PETROL~I~ CL File No · HOU-010079 CPI 2-010202-1 Date · March 08, 200~ Analysts' LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi fi(-1) microns glcm3 78 8870.5 800 14.68 .365 .546 32.88 1.09E+12 1.24E+03 2.633 79V 8871.5 800 15.86 .156 .266 49.69 5.04E+11 2.41E+02 2.640 79 8871.5 800 14.22 .413 .527 18.11 9.87E+12 1.27E+04 2.628 80 8872.5 800 14.88 .409 .525 18.75 7.98E+12 1.01E+04 2.630 81 8873.5 800 15.72 .496 .612 15.16 7.96E+ 12 1.23E+04 2.668 82V 8874.5 800 15.69 .175 .288 45.28 1.52E+11 8.15E+01 2.630 82 8874.5 800 15.77 .446 .678 34.12 5.52E+11 7.66E+02 2.628 83 8875.6 800 16.21 1.04 1.40 21.09 1.39E+11 4.56E+02 2.636 84 8876.5 800 16.18 .790 1.11 25.30 1.39E+11 3.45E+02 2.622 85 8877.7 800 17.57 3.01 3.75 14.35 1.39E+10 1.33E+02 2.670 86 8878.5 800 20.08 5.01 6.12 12.53 1.74E+09 2.82E+01 2.665 87 8879.5 800 20.13 10.3 12.0 9.26 4.41E+08 1.47E+01 2.633 88V 8880.5 800 20.84 6.57 7.89 11.14 1.23E+09 2.63E+01 2.675 88 8880.5 800 21.30 18.6 21.3 7.57 1.96E+08 t. 18E+01 2.627 89 8881.5 800 17.20 2.53 3.05 12.13 4.29E+10 3.52E+02 2.625 90 8882.6 800 15.95 .628 .894 27.14 3.16E+11 6.43E+02 2.635 91 8883.6 800 15.06 .366 .527 29.33 1.62 E+ 12 1.91 E+03 2.631 92V 8884.5 800 14.37 .043 .087 78.11 2.12E+13 2.95E+03 2.638 92 8884.5 800 14.63 .277 .413 33.41 2.30E+ 11 2.07E+02 2.627 93 8885.5 800 14.23 .112 .194 52.55 7.09E+10 2.57E+01 2.635 94V 8886.5 800 15.55 .106 .185 53.48 1.80E+12 6.20E+02 2.662 94 8886.5 800 15.92 .943 1.25 20.09 1.74E+11 5.15E+02 2.637 95 8887.5 800 16.22 1.08 1.44 20.52 1.25E+11 4.26E+02 2.631 96 8888.5 800 16.51 .831 1.16 25.19 1.99E+11 5.18E+02 2.619 97 8889.5 800 15.39 .515 .761 31.03 4.51E+11 7.25E+02 2.632 PRELIMINARY REPORT Page 5 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location · Alaska Fnr~l CL File No · HOU-010079 CPI 2-010202-1 Date · March 08, 2001 Analysts' LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi fi(-1) microns ~llcm3 98 8890.5 800 17.31 2.36 3.01 16.07 1.92E+10 1.45E+02 2.645 99 8891.5 800 18.48 4.18 5.27 14.86 2.57 E+09 3.42E+01 2.628 100V 8892.5 800 17.16 .083 .158 66.66 2.13E+13 5.34E+03 2.670 100 8892.6 800 18.00 2.62 3.33 15.82 1.51E+10 1.26E+02 2.627 101 8893.5 800 17.91 3.00 3.75 14.66 1.09E+ 10 1.04E+02 2.665 102 8894.5 800 16.39 .946 1.31 24.00 1.05E+ 11 3.13E+02 2.622 103V 8895.5 800 16.41 .107 .194 58.89 1.39E+12 4.51E+02 2.636 103 8895.6 800 15.45 .509 .735 28.93 4.23E+11 6.70E+02 2.620 104 8896.6 800 15.08 .355 .539 34.43 1.14E+12 1.26E+03 2.622 105 8897.8 800 14.31 .190 .307 42.87 4.58E+11 2.67E+02 2.628 106V 8898.5 800 14.36 .031 .064 82.28 2.02E+13 1.87E+03 2.623 106 8898.5 800 13.24 .092 .162 54.97 2.38E+ 12 6.69E+02 2.620 107 8899.5 800 14.39 .506 .585 10.20 1.23E+13 1.94E+04 2.617 108 8900.5 800 16.23 .687 .977 26.91 3.55E+11 7.63E+02 2.625 109 8901.5 800 17.16 1.51 2.00 19.61 6.85E+10 3.27E+02 2.614 110V 8902.5 800 15.23 .093 .162 54.31 2.56E+12 7.22E+02 2.629 110 8902.5 800 15.29 .619 .730 11.57 8.94E+12 1.73E+04 2.638 111 8903.2 800 15.22 .431 .549 17.95 9.63E+ 12 1.29E+04 2.626 112 8905.5 800 17.78 1.27 1.72 22.00 6.19E+10 2.54E+02 2.676 113V 8906.5 800 15.85 .069 .130 66.72 1.01E+13 2.24E+03 2.626 113 8906.5 800 16.38 .532 .782 30.48 4.58E+11 7.88E+02 2.620 114 8907.5 800 15.55 .402 .607 33.67 8.21E+11 1.07E+03 2.630 115 8908.5 800 13.74 .209 .278 22.81 9.03E+10 6.11E+01 2.625 116 8909.5 800 14.01 .188 .271 30.57 5.36E+11 3.26E+02 2.628 117V 8910.5 800 13.30 .014 .035 122.01 1.73E+13 7.85E+02 2.626 PRELIMINARY REPORT Page 6 CORE LABORATORIES, INC. HO US TON A D VA NCED TECHNOL 0 G Y CENTER Company · B P Exploration (Alaska) Inc. Well - S-104 Field · Westend Location · Alaska CL File No · HOU-010079 CPI 2-010202-1 Date · March 08, 200~ Analysts' Long/Koster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density ft psig % md psi ft(-1) microns ~l/cm3 117 8910.5 800 13.70 .127 .207 44.58 2.27E+11 9.36E+01 2.643 118 8911.5 800 13.53 .059 .115 71.66 6.35E+12 1.21E+03 2.627 119 8912.5 800 14.67 .271 .385 28.47 1.97E+11 1.73E+02 2.627 120V 8913.5 800 17.19 .365 .495 23.76 5.84E+12 6.89E+03 2.638 120 8913.5 800 15.72 .459 .582 17.55 7.44E+12 1.06E+04 2.624 121 8914.5 800 19.76 4.76 5.89 13.47 1.12E+09 1.71E+01 2.637 122 8915.5 800 21.59 7.35 8.87 11.40 7.16E+08 1.68E+01 2.673 123 8916.6 800 11.07 .014 .032 108.25 3.45E+13 1.39E+03 2.783 124 8917.5 800 13.44 .375 .439 11.32 1.22E+12 1.41E+03 2.635 125 8918.5 800 14.03 .210 .254 14.31 2.97E+11 1.92E+02 2.635 126V 8919.5 800 13.37 .013 .034 130.47 3.63E+13 1.42E+03 2.638 126 8919.5 800 13.21 .038 .079 82.90 7.24E+12 8.24E+02 2.636 127 8920.5 800 15.83 .575 .808 26.08 1.00E+12 1.80E+03 2.644 128 8921.5 800 15.63 .169 .295 52.19 2.48E+11 1.28E+02 2.649 129 8922.6 800 13.58 .050 .098 74.64 5.18E+12 7.69E+02 2.658 130 8923.5 800 15.78 .395 .581 31.21 1.22E+12 1.56E+03 2.656 131 8924.5 800 15.53 .039 .083 87.44 5.53E+12 6.96E+02 2.758 132V 8925.5 800 15.24 .028 .057 83.54 1.42E+14 1.27 E+04 2.668 132 8925.5 800 14.85 .063 .116 63.02 5.61E+12 1.14E+03 2.709 133 8926.5 800 17.61 .339 .527 36.88 5.02E+11 5.51E+02 2.667 134 8927.5 800 12.54 .039 .063 46.68 1.25E+ 13 1.59E+03 2.724 135V 8928.5 800 12.05 .005 .011 99.49 8.61E+14 1.38E+04 2.716 135 8928.5 800 9.19 .008 .021 134.47 9.34E+12 2.44E+02 2.783 136 8929.5 800 12.53 .065 .090 29.82 5.10E+12 1.07E+03 2.659 137 8930.6 800 12.08 .028 .050 60.36 2.35E+13 2.14E+03 2.650 PRELIMINARY REPORT Page 7 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. ~,._ Well · S-104 Field · Westend Location · Alaska rnna ~ CL File No · HOU-010079 CPI 2-010202-1 Date · March 08, 2001 Analysts' LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS Sample Depth Reservoir Porosity Permeability b(He) Beta Alpha Grain Number Net Overburden Klinkenberg I Kair Density fl: psig % md psi ft(-1) microns ~llcm3 138 8931.4 800 13.78 .150 139 8932.6 800 13.49 .068 140V 8933.5 800 12.79 .008 140 8933.5 800 12.48 .021 141 8934.5 800 12.08 .023 142 8935.6 800 12.36 .019 143 8936.3 800 12.62 .044 144 8937.6 800 13.10 .108 .189 18.28 6.52E+11 3.17E+02 2.656 118 53.78 1.36E+ 12 2.80E+02 2.646 012 43.60 4.69E+14 1.07E+04 2.645 040 70.40 2.79E+13 1.73E+03 2.647 044 69.55 3.49E+13 2.40E+03 2.648 041 90.78 2.19E+13 1.23E+03 2.645 071 46.21 3.91E+12 5.19E+02 2.644 143 23.11 2.69E+12 8.80E+02 2.645 PRELIMINARY REPORT Page 8 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company ' B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location : Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: Long/Koster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density [1: psig % md % Pore Volume g/cm3 Description 1 8778.6 800 14.40 .702 .750 38.3 53.9 2.719 2 8779.6 800 14.64 .201 .248 39.9 56.1 2.692 3 8781.6 800 15.40 .363 .421 61.4 32.6 2.729 4V 8782.2 800 14.83 .026 .050 26.8 59.1 2.704 4 8782.6 800 16.04 .379 .465 47.4 49.0 2.710 5V 8783.2 800 8.98 .006 .012 38.2 31.1 3.177 5 8783.7 800 9.05 .006 .017 37.5 34.5 2.975 6 8785.6 800 14.69 .030 .054 26.3 58.7 2.760 7V 8786.5 800 17.60 .052 .102 25.4 53.4 2.881 7 8786.7 800 17.99 .166 .274 22.9 55.5 2.889 8 8787.8 800 22.53 1.58 2.06 26.0 49.4 2.904 9 8788.3 800 20.10 1.29 1.61 34.3 36.9 2.714 10 8789.8 800 17.88 1.04 1.36 31.7 36.9 2.847 11V 8790.2 800 19.07 .838 1.16 32.2 36.5 2.858 11 8790.5 800 19.92 5.27 6.14 . 32.1 38.5 2.935 12 8791.6 800 22.70 2.66 3.48 44.0 30.5 3.001 13 8792.6 800 23.45 4.41 5.42 28.9 42.4 2.906 14V 8793.2 800 21.55 1.78 2.32 38.2 34.7 2.835 14 8793.6 800 26.31 12.5 14.6 34.3 35.0 2.962 15 8794.4 800 22.24 5.67 6.86 30.8 41.6 2.880 16 8795.3 800 20.83 11.8 13.7 34.2 36.1 2.983 16V 8795.8 800 23.75 20.7 23.7 38.6 30.5 2.991 17 8796.3 800 24.56 22.6 26.1 43.0 25.8 2.961 18 8797.2 800 16.97 2.07 2.68 32.1 35.3 2.861 19 8801.4 800 21.59 50.0 53.9 36.9 25.9 2.686 Sst gry vf-f slily shy frac pbl Trace mica Sst gry vf-f shy lams frac Trace mica Sst gry vf-f slily shy frac Trace mica Sst gry vf-f slily shy Trace mica Sst gry vf-f slily shy frac Trace mica Sltst gry silly Imy sid sid Trace mica Sltst gry slily Imy sid Trace mica Sst gry vf-f slily shy glauc Trace mica Sst gry vf-f slily shy glauc Trace mica Sst gry vf-f slily shy glauc Trace mica Sst gry vf-f slily shy frac glauc Trace mica Sst gry vf-f slily shy glauc Trace mica Sst gry vf-f slily shy glauc Trace mica Sst gry vf-f slily shy glauc Trace mica Sst gry vf-f slily shy slily Imy frac sid Trace mica Sst gry vf-f slily shy pit glauc Trace mica Sst gry vf-f pit glauc Trace mica Sst brn vf-f slily shy glauc Trace mica Sst brn vf-f silly shy frac glauc Trace mica Sst brn vf-f slily shy glauc Trace mica Sst brn vf-f slily shy glauc Trace mica Sst brn vf-f slily shy pit glauc Trace mica Sst brn vf-f slily shy pit glauc Trace mica Sst brn vf-f slily shy glauc Trace mica Sst brn vf-f silly shy slily Imy glauc Trace mica PRELIMINARY REPORT Page '1 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location : Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume g/cm3 Description 20 8802.5 800 9.72 .038 .055 26.8 31.1 2.835 21 8803.5 800 25.00 317 327 45.3 22.1 2.829 22 8804.6 800 21.48 74.0 79.3 42.0 19.4 2.687 23V 8805.3 800 20.69 15.7 18.1 39.7 21.1 2.693 23 8805.5 800 20.26 29.6 32.9 39.7 21.6 2.685 24 8806.5 800 21.49 54.0 58.6 42.9 19.6 2.685 25 8807.5 800 19.38 13.4 15.6 41.5 22.0 2.672 26V 8808.1 800 19.12 3.35 4.27 44.2 20.6 2.670 26 8808.5 800 19.40 13.7 15.9 39.3 24.9 2.688 27 8809.5 800 20.61 26.5 29.7 43.4 20.3 2.697 28 8810.4 800 22.02 33.0 36.9 49.2 11.8 2.718 29V 8811.3 800 20.56 15.1 17.4 41.2 19.2 2.708 29 8811.6 800 19.90 24.3 27.4 37.9 20.3 2.713 30 8812.5 800 21.45 49.1 53.6 33.8 23.7 2.729 31 8813.6 800 21.27 49.1 53.5 49.0 13.2 2.733 32V 8814.2 800 21.79 33.8 37.3 42.5 22.0 2.750 32 8814.5 800 22.01 73.7 79.0 43.9 21.6 2.736 33 8815.5 800 23.00 143 150 52.4 20.8 2.721 34 8825.5 800 19.06 10.6 12.4 41.5 27.8 2.667 35V 8826.1 800 18.78 2.89 3.61 44.4 24.9 2.651 35 8826.5 800 19.11 12.8 14.9 38.3 27.5 2.652 36 8827.7 800 5.20 .001 .002 42.7 30.3 2.714 37 8828.5 800 18.53 8.16 9.76 40.5 25.8 2.649 38V 8829.1 800 18.70 2.92 3.73 46.7 23.1 2.655 38 8829.6 800 19.77 11.8 13.9 43.7 24.6 2.658 39 8830.5 800 19.78 10.3 12.1 43.4 24.5 2.662 Sst brn vf foss Imy cem frac glauc pyr Sst gry vf-f slily Imy glauc Trace mica Sst brn vf-f slily shy pyr Sst brn vf-f slily shy pyr Sst brn vf-f slily shy pit pyr Sst brn vf-f slily shy glauc Trace mica Sst brn vf-f shy lams glauc Trace mica Sst brn vf-f slily shy pyr Sst brn vf-f slily shy pyr Sst brn vf-f slily shy calc incl pyr Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily Imy pyr Trace mica Sst brn vf-f slily Imy pyr Trace mica Sst brn vf-f slily Imy Trace pyr Sst brn vf-f slily Imy Trace pyr Sst brn vf-f slily Imy pyr Trace mica Sst brn vf-f slily shy Imy inc Trace mica Sst brn vf-f silly shy Trace mica Sst brn vf slily shy Trace mica Sltst gry Imy Trace mica Sst brn vf-f shy lams Trace mica Sst brn vf-f slily shy slily Imy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica PRELIMINARY REPORT Page 2 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location · Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume glcm3 Description 40 8832.5 800 20.35 8.08 9.73 40.2 24.9 2.663 41V 8832.7 800 19.65 3.52 4.46 45.5 22.8 2.664 41 8833.5 800 19.56 7.58 9.13 42.2 26.8 2.657 42 8834.6 800 19.53 9.56 11.3 40.0 27.3 2.672 43V 8835.1 800 19.05 2.47 3.14 45.9 24.7 2.673 43 8835.5 800 19.93 9.04 10.7 41.5 27.0 2.672 44 8836.5 800 20.68 13.4 15.5 40.6 25.6 2.675 45 8837.5 800 19.99 10.4 12.2 38.2 27.1 2.671 46V 8838.1 800 19.72 2.66 3.38 43.3 25.0 2.669 46 8838.5 800 19.53 5.51 6.73 41.1 27.1 2.687 47 8839.5 800 20.28 11.3 13.2 43.2 26.3 2.656 48 8840.5 800 16.33 .756 1.06 31.1 41.5 2.657 49V 8841.1 800 18.25 .453 .671 49.9 30.9 2.658 49 8841.6 800 17.36 1.31 1.76 37.6 37.7 2.655 50 8842.5 800 16.07 .446 .660 29.9 45.2 2.749 50V 8842.6 800 15.98 .116 .201 34.9 36.1 2.707 51 8843.5 800 14.99 .350 .477 29.3 45.7 2.676 52V 8844.1 800 17.03 .336 .516 40.3 31.9 2.629 52 8844.5 800 17.16 1.43 1.94 36.0 37.5 2.636 53 8845.5 800 16.69 1.15 1.56 36.7 37.8 2.642 54 8846.5 800 19.37 6.53 7.91 42.0 31.4 2.638 55V 8847.1 800 19.65 3.07 3.83 48.5 21.9 2.644 55 8847.5 800 20.85 10.6 12.4 52.5 25.5 2.642 56 8848.5 800 19.56 6.54 7.95 41.1 28.2 2.635 57 8849.5 800 20.02 13.1 15.2 47.3 23.0 2.641 Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy slily Imy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f Imy inc Trace mica Sst brn vf-f slily shy slily Imy Trace mica Sst brn vf-f slily shy Imy inc Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy slily Imy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy Imy inc Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy lams Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f shy lams Imy inc Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f shy lams slily Imy Trace mica Sst brn vf-f shy lams Trace mica Sst brn vf-f slily shy Trace mica PRELIMINARY REPORT Page 3 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. Well · S-104 Field · Westend Location : Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: Long/Koster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume ~llcm3 Description 58V 8850.1 800 19.60 2.53 3.31 42.0 23.1 2.671 58 8850.4 800 20.24 10.9 12.9 40.0 26.7 2.667 59 8851.5 800 19.78 12.7 14.7 41.1 26.7 2.656 60 8852.5 800 18.64 10.4 12.1 38.9 27.3 2.651 61V 8853.5 800 19.99 2.81 3.57 43.2 25.3 2.650 61 8853.5 800 19.84 9.24 10.9 41.4 26.1 2.648 62 8854.5 800 20.08 12.4 14.6 37.8 26.1 2.639 63 8855.5 800 16.27 .992 1.36 32.2 37.8 2.636 64 8856.5 800 16.61 1.80 2.31 50.4 19.4 2.645 65 8857.5 800 16.59 2.19 2.73 35.9 31.9 2.660 66 8858.5 800 14.94 .120 .204 28.3 43.2 2.944 67V 8859.5 800 14.40 .045 .1 O0 35.4 35.1 2.643 67 8859.5 800 14.14 .618 .643 29.0 43.2 2.642 68 8860.5 800 14.77 .219 .342 31.7 38.4 2.641 69 8861.5 800 16.85 .840 1.20 70.1 1.2 2.637 70 8862.5 800 17.52 1.84 2.39 40.5 29.7 2.639 71V 8863.5 800 18.88 2.24 2.87 45.2 20.9 2.631 71 8863.6 800 18.48 4.59 5.61 42.7 24.2 2.666 72 8864.5 800 19.76 9.33 10.9 44.0 22.3 2.646 73 8865.5 800 19.57 6.56 7.85 39.1 23.1 2.675 74 8866.5 800 21.42 25.3 28.4 44.2 17.6 2.642 75 8867.5 800 20.31 11.7 13.7 41.9 22.5 2.632 76V 8868.5 800 19.17 2.22 2.85 45.1 20.4 2.627 76 8868.5 800 19.42 8.75 10.4 41.7 23.7 2.638 77 8869.5 800 17.14 2.02 2.62 37.1 28.1 2.627 Sst brn vf-f Imy inc Trace mica Sst brn vf-f slily shy Imy inc Trace mica Sst brn vf-f slily shy Imy inc Trace mica Sst brn vf-f slily shy Imy inc Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy lams Imy inc pyr Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy frac pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy Imy inc pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f shy lams pyr Trace mica PRELIMINARY REPORT Page 4 CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. ~.~ Well · S-104 Field · Westend Location · Alaska CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume g/cm3 Description 78 8870.5 800 14.68 .365 .546 29.8 34.7 2.633 79V 8871.5 800 15.86 .156 .266 37.0 26.6 2.640 79 8871.5 800 14.22 .413 .527 32.0 36.3 2.628 80 8872.5 800 14.88 .409 .525 29.9 34.9 2.630 81 8873.5 800 15.72 .496 .612 28.6 34.7 2.668 82V 8874.5 800 15.69 .175 .288 33.3 30.7 2.630 82 8874.5 800 15.77 .446 .678 33.8 33.8 2.628 83 8875.6 800 16.21 1.04 1.40 30.0 31.9 2.636 84 8876.5 800 16.18 .790 1.11 29.3 32.0 2.622 85 8877.7 800 17.57 3.01 3.75 36.8 26.1 2.670 86 8878.5 800 20.08 5.01 6.12 38.8 24.1 2.665 87 8879.5 800 20.13 10.3 12.0 41.5 22.8 2.633 88V 8880.5 800 20.84 6.57 7.89 25.5 20.1 2.675 88 8880.5 800 21.30 18.6 21.3 44.0 20.5 2.627 89 8881.5 800 17.20 2.53 3.05 33.1 30.0 2.625 90 8882.6 800 15.95 .628 .894 30.4 32.4 2.635 91 8883.6 800 15.06 .366 .527 27.1 37.6 2.631 92V 8884.5 800 14.37 .043 .087 26.4 39.2 2.638 92 8884.5 800 14.63 .277 .413 27.9 37.6 2.627 93 8885.5 800 14.23 .112 .194 24.4 41.3 2.635 94V 8886.5 800 15.55 .106 .185 29.2 34.7 2.662 94 8886.5 800 15.92 .943 1.25 28.8 35.0 2.637 95 8887.5 800 16.22 1.08 1.44 30.9 34.4 2.631 96 8888.5 800 16.51 .831 1.16 33.0 31.8 2.619 97 8889.5 800 15.39 .515 .761 27.6 35.9 2.632 Sst brn vf-f slily shy Trace mica Sst brn vf-f shy pyr Trace mica Sst bm vf-f shy pyr Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f shy Imy inc pyr Trace mica Sst brn vf-f shy Trace mica Sst brn vf-f shy lams Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f shy Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f shy lams pyr Trace mica Sst brn vf-f shy Imy inc Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f slily shy pyr Trace mica Sst brn vf-f shy Trace mica Sst brn vf-f shy Imy inc Trace mica Sst brn vf-f shy Trace mica Sst brn vf-f shy Trace mica Sst brn vf-f shy Imy inc Trace mica Sst brn vf-f shy Trace mica PRELIMINARY REPORT Page 5 CORE LABORATORIES, INC. HO US TON A D VA NCED TECHNOL 0 G Y CENTER Company · B P Exploration (Alaska) Inc. ~.~ Well · S-104 Field · Westend Location : Alaska ~n~ ~ CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: Long/Koster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume ~llcm3 Description 98 8890.5 800 17.31 2.36 3.01 35.8 29.1 2.645 Sst 99 8891.5 800 18.48 4.18 5.27 36.8 30.8 2.628 Sst IOOV 8892.5 800 17.16 .083 .158 32.5 34.7 2.670 Sst 100 8892.6 800 18.00 2.62 3.33 35.6 33.6 2.627 Sst 101 8893.5 800 17.91 3.00 3.75 36.7 26.3 2.665 Sst 102 8894.5 800 16.39 .946 1.31 23.6 30.6 2.622 Sst 103V 8895.5 800 16.41 .107 .194 52.3 29.7 2.636 Sst 103 8895.6 800 15.45 .509 .735 27.5 34.4 2.620 Sst 104 8896.6 800 15.08 .355 .539 26.6 35.4 2.622 Sst 105 8897.8 800 14.31 .190 .307 16.2 40.7 2.628 Sst 106V 8898.5 800 14.36 .031 .064 20.4 41.5 2.623 Sst 106 8898.5 800 13.24 .092 .162 24.3 43.1 2.620 Sst 107 8899.5 800 14.39 .506 .585 22.1 41.3 2.617 Sst 108 8900.5 800 16.23 .687 .977 27.2 33.6 2.625 Sst 109 8901.5 800 17.16 1.51 2.00 23.4 35.6 2.614 Sst 110V 8902.5 800 15.23 .093 .162 22.7 36.6 2.629 Sst 110 8902.5 800 15.29 .619 .730 22.7 37.8 2.638 Sst 111 8903.2 800 15.22 .431 .549 20.0 38.3 2.626 Sst 112 8905.5 800 17.78 1.27 1.72 30.1 25.3 2.676 Sst 113V 8906.5 800 15.85 .069 .130 22.8 41.2 2.626 Sst 113 8906.5 800 16.38 .532 .782 14.7 37.5 2.620 Sst 114 8907.5 800 15.55 .402 .607 13.2 43.0 2.630 Sst 115 8908.5 800 13.74 .209 .278 14.7 50.0 2.625 Sst 116 8909.5 800 14.01 .188 .271 14.0 47.3 2.628 Sst 117V 8910.5 800 13.30 .014 .035 11.8 53.1 2.626 Sst brn vf-f shy Imy inc Trace mica brn vf-f shy lams Trace mica brn vf-f shy Trace mica brn vf-f shy Trace mica brn vf-f shy Trace mica brn vf-f shy Imy inc pyr Trace mica brn vf-f shy pyr Trace mica brn vf-f shy Trace mica brn vf-f shy Imy inc Trace mica brn vf-f shy lams pyr Trace mica brn vf-f shy Trace mica brn vf-f shy frac Trace mica brn vf-f shy frac Trace mica brn vf-f shy frac Trace mica brn vf-f shy lams frac Trace mica brn vf-f shy pyr Trace mica brn vf-f shy Imy inc frac pyr Trace mica brn vf-f shy Imy inc pyr Trace mica brn vf-f shy Trace mica brn vf-f shy Trace mica brn vf-f shy pyr Trace mica brn vf-f shy Imy inc frac pyr Trace mica brn vf-f shy frac pyr Trace mica brn vf-f shy Imy inc frac pyr Trace mica brn vf-f shy frac Trace mica PRELIMINARY REPORT Page 6 CORE LABORATORIE$, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Company · B P Exploration (Alaska) Inc. ~... Well · S-104 Field · Westend Location : Alaska Eor~ ~ pE'rnOL~U~ CL File No: HOU-010079 CPI 2-010202-1 Date: March 08, 2001 Analysts: LonglKoster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume g/cm3 Description 117 8910.5 800 13.70 .127 .207 11.6 51.5 2.643 118 8911.5 800 13.53 .059 .115 11.2 52.2 2.627 119 8912.5 800 14.67 .271 .385 7.4 50.9 2.627 120V 8913.5 800 17.19 .365 .495 8.1 40.2 2.638 120 8913.5 800 15.72 .459 .582 11.0 43.0 2.624 121 8914.5 800 19.76 4.76 5.89 7.8 45.3 2.637 122 8915.5 800 21.59 7.35 8.87 8.1 46.9 2.673 123 8916.6 800 11.07 .014 .032 19.7 52.1 2.783 124 8917.5 800 13.44 .375 .439 14.2 54.3 2.635 125 8918.5 800 14.03 .210 .254 60.9 14.6 2.635 126V 8919.5 800 13.37 .013 .034 14.6 56.1 2.638 126 8919.5 800 13.21 .038 .079 14.6 58.2 2.636 127 8920.5 800 15.83 .575 .808 9.2 51.7 2.644 128 8921.5 800 15.63 .169 .295 6.0 54.2 2.649 129 8922.6 800 13.58 .050 .098 10.8 56.8 2.658 130 8923.5 800 15.78 .395 .581 3.1 54.6 2.656 131 8924.5 800 15.53 .039 .083 16.6 51.5 2.758 132V 8925.5 800 15.24 .028 .057 11.5 67.0 2.668 132 8925.5 800 14.85 .063 .116 16.7 64.8 2.709 133 8926.5 800 17.61 .339 .527 9.4 69.2 2.667 134 8927.5 800 12.54 .039 .063 17.2 67.2 2.724 135V 8928.5 800 12.05 .005 .011 24.2 59.6 2.716 135 8928.5 800 9.19 .008 .021 36.2 44.9 2.783 136 8929.5 800 12.53 .065 .090 13.2 76.0 2.659 137 8930.6 800 12.08 .028 .050 13.4 77.2 2.650 Sst brn vf-f shy frac pyr Trace mica Sst brn vf-f shy frac pyr Trace mica Sst brn vf-f shy frac pyr Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f shy Imy inc frac Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f shy Trace mica Sst brn vf-f shy frac Trace mica Sst brn vf-f shy Imy inc frac Trace mica Sst brn vf-f shy frac Trace mica Sst brn vf-f shy frac Trace mica Sst brn vf-f shy Imy inc pyr Trace mica Sst brn vf-f shy frac pyr Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f shy pyr Trace mica Sst brn vf-f pyr Trace mica Sst brn vf-f shy glauc pyr Trace mica Sst brn vf-f frac glauc Trace mica Sst brn vf-f Imy inc glauc Trace mica Sst grn-brn vf-f Imy inc glauc Trace mica Sst brn vf-f shy glauc Trace mica Sst brn vf shy Imy inc Trace mica Sst brn vf shy Imy Trace mica Sst brn vf-f shy frac pyr Trace mica Sst brn vf-f shy frac Trace mica PRELIMINARY REPORT Page 7 CORE LABORATORIE$, INC. HO US TON A D VA NCED TECHNOL 0 G Y CENTER Company · B P Exploration (Alaska) Inc. ~.,. Well · S-104 Field · Westend Location · Alaska Eor~ ~ p~T~OL~U~ S~3tV]££S CL File No · HOU-010079 CPI 2-010202-1 Date · March 08, 2001 Analysts · Long/Koster CMS-300 CONVENTIONAL PLUG ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Reservoir Porosity Permeability Saturation Grain Number Net Overburden Klinkenberg I Kair Oil I Water Density ft psig % md % Pore Volume g/cm3 Description 138 8931.4 800 13.78 .150 .189 17.2 70.9 2.656 139 8932.6 800 13.49 .068 .118 15.3 67.8 2.646 140V 8933.5 800 12.79 .008 .012 11.8 72.1 2.645 140 8933.5 800 12.48 .021 .040 12.8 73.0 2.647 141 8934.5 800 12.08 .023 .044 11.9 75.8 2.648 142 8935.6 800 12.36 .019 .041 12.4 75.4 2.645 143 8936.3 800 12.62 .044 .071 11.8 74.2 2.644 144 8937.6 800 13.10 .108 .143 14.4 71.5 2.645 Sst brn vf-f shy frac Trace mica Sst brn vf-f shy frac pyr Trace m~ca Sst brn vf-f shy frac pyr Trace m~ca Sst brn vf-f shy frac pyr Trace m~ca Sst brn vf-f shy frac pyr Trace m~ca Sst brn vf-f shy frac pyr Trace m~ca Sst brn vf-f shy frac pyr Trace m~ca Sst brn vf-f shy frac pyr Trace m~ca PRELIMINARY REPORT Page 8 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATI'N: Sherrie NO. 994 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 · Anchorage, AK 99501 2/20/01 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-104 21052 MSD DIPS & FMI IMAGES 01/27/01 1 S-104 21052 FMI IMAGES (1:12 SCALE) 01/27/01 1 S-104 21052 CMR & FMI COMPOSITE IMAGES 01/27/01 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 ,oo CEtVED Anchorage AK 99508-4254 ~,~ JJ .... - Date Delivered: Schlumberger DCS 3940 Arctic BIvd Suite 300 Anchorage AK 99503-5789 ATrN: Sherrie Peceived~ 03-Feb-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well S-104 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 298.00' MD 'MD 9,196.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager Attachment(s) 03-Feb-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-104 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 298.00' MD 'MD 9,196.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, ~A/.i,qiem-T. Alien Survey Manager Attachment(s) R.ECE[VED 03-Feb-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well S-104 GYRO Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 'MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager Attachment(s) 2/19/01 Schhmtberg Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AI'rN: Sherrie NO. 989 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-104 21071 USIT 020201 1 LS-104 21053 PEX & AIT,DSI,FMI and CMR 012701 1 S-104 21053 PEX-AIT 012701 1 1 S-104 21053 PEX-3 DET DEN CNL 012701 1 1 S-104 21053 PEX-SSTVD 012701 1 1 S-104 21053 RFT 012701 1 1 , S-104 21053 DSI 012701 ] 1 ; S-104 21053 CMR 012901 ] 1 j, 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: Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 Al-tN: Sherrie Received Schlumberger Alaska Dala and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 A1TN: Sherrie NO. 975 Company: Alaska Oil & Gas Cons Comm Alln: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 2/13/01 Field: Aurora Well Job # Log Description Date Color Sepia CD , . S-104 21051 PROCESSED CMR RESULTS 012701 1 .. .. . ,, . ., . . - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploralion (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: c,q Schlumberger DCS 3940 Arclic Blvd Suite 300 Anchorage AK 99503-5789 AYfN: Sherrie Recelved~ ~ PETROLEUJq SERVICES Core Labor_atories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99618 To: Alaska Oil & Gas Conservation Commission 333 W. 7th #100 Anchorage, Alaska 99501 ~907-279-1433 Date: 2/5101 Well,Name: B.P. Exploration S-104 Number of Samples: 166 Contact: Ed Westergaard 564-5972 Description of Material: Core Chip Samples Depths: 8765-8937.6 * · No samples taken from 8765 to 8771 .... Preserved Core Sent By: Tim Lawlor Core Laboratories Received By: S T A T E OF ALASKA TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSER VA TION COMMISSION 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P 0 Box 196612 Anchorage, Ak 99519-6612 Re~ Prudhoe Bay Unit S- 104i BP Exploration (Alaska) Inc. Permit No: 200-196 Sur Loc: 4646'NSL, 4494'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 3622'NSL, 1014'WEL, Sec. 27, T12N, R12E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 performed 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, Commissioner BY ORDER OF THE COMMISSION DATED this ._5"/4 day of January, 2001 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA (' ~ ALASt'~ . OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~ Drill [] Redrill I lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] .l~ltiple Zone .2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.5' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ~2-~.~'~'TZ~AD,~.,028258 4. Location of well at surface 7. Unit or 1~olberty Name 11. Type Bond (See 2O AAC 25.025) 4646' NSL, 4494' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3602' NSL,,~.'._WEI~, SEC. 27, T12N, R12E, UM S-104i Number 2S100302630-277 At total depth"-~z"z" .~t,... 9. Approximate spud date 3622' NSL, 1014' WEL, SEC. 27, T12N, R12E, UM 1.~J. e4/00' ~,~,~//'¢o '~ Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028257, 1014' MDI S-105 isl$'away at 350' MD 2560 9344' MD / 7183' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 54 o Maximum surface 2765 psig, At total depth (TVD) 6700' / 3435 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weiqht Grade Couplinq Lenqth MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 3697' Surface Surface 3726' 2864' 401 sx Arcticset Lite II1~ 260 sx 'G' 8-3/4" 7" 26# L-80 BTC-M 9315' Surface ~ Surface 9344' 7183' 592 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateRECEIVED Production Liner NOV 2 2, Perforation depth: measured Alaska Oil & Gas Cons. Commission ^nchorage '~ ' ..... true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~---------------"~--- ~'"~, ~ Title Senior Drilling Engineer Date : ;:::: :':.i i i.::" '"' ::'::"" :"',i', ?';' .:.ii': .; ,.',".' :.',..:'.:,,".;":;:'.,?:i.:~i':::?",.:: :,:". ;,,",":'. ~' '.'"::",~:::'i'::.,'.':"',::~.~:':'! :~;!:~L~:~:::;~;C~rn~i~n:~U's~::~:~:;::~?~:~:~:~!~?''' ::.:':.":,:::'~..:,.:' ':,':!'"':'.'..:..".. '. :,' "..'.' ,.":; ::.,i:'..': :;. i':':.'. ,.:,:':;, .. i":.. '; ;.'.: :'"'..~ .'. Permit Number I APl Number J Approval DAte, I See cover letter - / 50- o .2. ~.~///L~)~)~//~// for other requirements Conditions of Approval: Samples Required [] Yes I~ No Mud Lo~Require~ [] Yes I~No Hydrogen Sulfide Measures I]~[Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K 'J~3.5K Other: ~ YT' I~ Ca:~.w,,O_t,,"~ (~,,,~x'¥-{ ORIGINAL p, .:)~,,,, :-,-. ,.... by order of Approved By D T';,;~,,,,,I, , Commissioner the commission Date ¢//' // Form 10-401 Rev. 12-01-85 Triplicate To: 2000 Blair Wondzell, AOGCC Date: December 27, From: Phil Smith Subject: Dispensation for 20 AAC 25.035 (c) on Aurora S-104 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent six Aurora/Polaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first six surface holes for the Aurora/Polaris development were drilled no deeper than the shale underlying the SV-1 sands; S-104 is planned to TD in the shallower SV-3 shale, as did the most recent wells. The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is +500' TVD above the Ugnu horizon. The shallowest and most recent RFT points recorded in the area are from S- 201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-104 is planned to reach 9.6 ppg mud weight before TD at 2,800' TVDss. This planned mud weight, and the aforementioned RFT data, is plotted on the attached chart. Supporting surface hole gas detection information is on file with the AOGCC from recently drilled S- 105. Your consideration of the waiver is appreciated. Sincerely, Phil G. Smith ADW Engineer 564-4897 5OO 1000 1500 2000 2500 3OOO 35OO 4OO0 Aurora/Polaris Surface Hole Mud Weight MW (ppg) 8 9 10 "~*? S-100 ~®- S-101 ~$-102 ~S-105 -'~------ S-103 (~ S~201 ~ RFT DATA -~- S-104 Plan ~¢ S-216 PGS 11/30/2000 S-213 Drilling Permit .~-104i (200-196) Subject: S-104i (200-196) Date: Fri, 22 Dec 2000 09:27:15-0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Phil Smith <smithpgl@bp.com> CC: Julie Heusser <julie_heusser@admin.state.ak. us>, Terrie Hubble <hubbletl@bp.com> Phil, I have staKed/continued reviewing your application for S-104i and we need a few items for the well file. Nothing major. When originally submitted, you planned to drill and case then move off due to lack of some completion equipment. You then decided to delay the well spud to allow the equipment to arrive. VVould you please send us an email noting these changes. Also, this permit application was received prior to granting the opportunity for you to apply for a diverter waiver on a well by well basis. Could you please send the updated information based on the latest surface holes on S pad. I will be out of the office through the first week of January, so please send your response to Julie. Thanks much. Tom Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 12/22/00 9:27 AM S-104i Permit Subject: S-104i Permit Date: Fri, 22 Dec 2000 19:01:06 -0000 From: "Smith, Phil G (FAIR)" <SmithPGl@BP.o~m> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "PBU, Drlg Rig 9es" <PBUDrlgRig9es@BP.com> Tom, S-104i is currently scheduled to spud approximately Jan 10th, 2001. We expect the completion equipment to have arrived bythat time, so there will be no need "temporarily halt operations" as stated in the permit application. Nabors 9ES will stay on the well for the entire drill and complete as summarized in the drilling permit application. The current plan is to move to NGI-04 v, orkover after S-104i, therealter staying on the east side of the field to perform workovers, sidetracks and new well operations east of the sag river until breakup in the spring. Will keep you posted on the rig schedule as it evolves. Thanks and Happy Holidays! Phil 1 of 1 12/22/00 11:39 AM I Well Name: I S-104i Drill and Complete Plan Summary I Type of Well (service / producer /injector): I Injector Surface Location: Secondary Target: Schrader Bluff Target Location: Kuparuk Bottom Hole Location: X = 618,930.01 Y = 5,980,849.97 4646' FSL 4494' FEL S35 T12N R12E Umiat X = 618,060.00 Y = 5,984,990.00 3520' FSL 13' FEL S27, T12N, R12E Umiat X = 617,250.00 Y: 5,985,060.00 3602' FSL 822' FEL S27, T12N, R12E Umiat X = 617,057.57 Y = 5,985,076.63 3622' FSL 1014' FEL S27, T12N, R12E Umiat I AFE Number: 15M0009 I I Estimated Start Date:112/04/2000 9344' ~7183' J I Rig' I Nabors9ES I Operating days to complete: 120.6 [ BF/MS: ~ [ RKB: ~ 64.5' I Well Design (conventional, slimhole, etc.):I Ultra Slimhole Longstring I Objective' I Kuparuk Formation, Schrader Bluff secondary RECEIVED ^.chorage S-104i Permit to Drill Page 1 Mud Program: 12-1/4" Surface Hole (0-3726'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Initial 8.5-9.1 300 75 12 19/55 NC Interval TD 9.1-9.6 65 20-25 22-25 12/25 <10cc 8-3/4" Upper Intermediate Hole (3726' - 8900'): 4% KCI Interva'l ' Density Viscosity, YP 'PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.2 42-52 15-25 10-19 9.0-9.5 6cc <14 shoe to to by HRZ HRZ <5 8-3/4" Production Zone (8900' - 9344') Bland Corincj Fluid + 4% KCI Interval Density ~iscosity Y~ PV pH ~ APl HTHP (ppg) (seconds) Filtrate Filtrate Production 10.5 40-50 18-28 28-38 8.0-8.5 <5 <7.5 Hole Directional: KOP: 1300' Maximum Hole Angle: Close Approach Wells: 54° at 2200' MD - Intermediate hole Shut in S-105 for moves, Surface nudge at 300' for S-105 Logging Program: Surface Intermediate / Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / PWD & Cuttings Gas & Samples Open Hole: PEX/Sonic, CMR/FMI, RFT w/samples Cased Hole: USIT S-104i Permit to Drill Page 2 Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 2045 1800 SV3 / T5 3563 2702 SV1 4399 3195 Unknown, SB-01 RFT = 9.45 ppb EMW .'~ UG4/K15 (top Is~ coal) 4894 3487 Ugnu top (UG4A) 5063 3587 Unknown, 10.5 ppg MW required on SB-01 UG3 5608 3909 UG1 6320 4421 SB-01 RFT = 9.03 ppg EMW Schrader (Ma Sand) 6680 4740 8.48 ppg Schrader (Mb1 Sand) 6744 4790 8.45 ppg Schrader (Mb2 Sand) 6800 4840 8.44 ppg Schrader (Mc Sand) 6866 4900 8.48 ppg Schrader (Na Sand) 6933 4960 8.45 ppg Schrader (Nb Sand) 6950 4975 8.45 ppg Schrader (Nc Sand) 6989 5010 8.43 ppg Schrader (OA Sand) 7044 5060 8.36 ppg Schrader (OBa Sand) 7095 5105 8.34 ppg Schrader (OBb Sand) 7134 5140 8.32 ppg Schrader (OBc Sand) 7190 5190 8.30 ppg Schrader (OBd Sand) 7234 5230 8.29 ppg Schrader (OBe Sand) 7290 5280 8.27 ppg Base Schrader (Obf) 7335 5320 8.24 ppg [HRZ "upper" top] 8544 6402 HRZ top 8701 6542 HRZ Base 8876 6699 Kuparuk C4B 8895 6716 Top target interval, 9.84 ppg EMW Kuparuk C4A 8911 6730 Kuparuk C3B 8923 6741 Kuparuk C3A 8965 6778 Base Target Interval Kuparuk C2 9012 6821 Kuparuk C1 9027 6834 Kuparuk B, LCU 9048 6853 Kuparuk A6 9117 6914 Kuparuk A5 9125 6921 Kuparuk A4 9146 6941 Miluveach 9189 6979 TD 9344 7117 TD Casin¢ /Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 12-1/4" 9-5/8" 40# L-80 BTC-M 3697' GL 3726'/2864' 8-3/4" 7" 26# L-80 BTC-M 9315' GL 9344'/7183' Tubing 4-1/2" 9.3# L-80 NSCT ---8746' GL 8775'/6675' S-lO4i Permit to Drill Page 3 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. Casinc. Basis: Size 19-5/8" Surface I Lead: Based on 2045' of annulus in the permafrost @ 125% excess and 825' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe tract volume. Tail TOC: At -2870' MD (2364' TVDbkb). Lead 1 317 bbl / 1780 f¢ / 401 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 68 bbl / 382 f¢ / 329 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Size 17" Intermediate Ist Stage Basis: I Tail: to 1000' MD above Kuparuk target and 30% excess + 80' shoe tract volume I Tail TOC: 7900' MD I Ibbls/3o3 260 Total Cement Volume: Tail 54 f¢/ sks of Dowell Premium G blend at 15.8 ppg and 1.16 cf/sk. Casing Size 17" Intermediate 2n" Stage Basis: ILead' to 500' MD above the Ugnu 4A Formation and 30% excess Lead TOC: 4550' MD Tail: Based on 100' below the Schrader Bluff to 500' above, plus 30% excess + shoe Tail TOC: 6240' MD ITotal Cement Volume: I Lead 59 bbls / 331 f¢/119 sks of Dowell Extended blend at I11.5 ppg and 2.79 cf/sk. Tail 1 44 bbls / 247 f¢/213 sks of Dowell Premium 'G' at 15.8 I ppg and 1.16 cf/sk. Well Control: Surface hole will be drilled without diverter. Dispensation is expected prior to spud of the well for surface holes drilled on Prudhoe Bay S-Pad. Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- , Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Planned completion fluid: 3435 psi @ 6700' TVDss - Kuparuk Target Top 2765 psi @ surface (based on BHP and a full column of gas from D 3500 psi 8.6 ppg seawater / 6.8 ppg Diesel NOV ?., ?, ?qnq Alaska Oil & ,,Gas Cor~. ~ssi~n S-104i Permit to Drill Page 4 Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · S-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad has been 60 ppm (S-37, 12/2/98) DRILLING CLOSE APPROACH: At 15' south of the the S-104i surface location, S-105 is the closest well to the S-104i well plan. The well will remain unperforated and secure until after the S-104i completion and rig down. S-104i begins divergence from S-105 at the 300' MD KOP and passes all close approach criteria. SURFACE HOLE SECTION' · Directional control has been an issue in the recent S-pad surface holes. Response to sliding in the permafrost was hampered through the gravel intervals, presumably the washed-out sections. Doglegs should be kept below 12.5° for casing running. · The KOP at 300' MD is required to keep the well angle to the target Iow for wireline accessibility and wellbore proximity to S-105. Though S-105 passes all close approach criteria, the 15' well center must be given due respect until the wells diverge. · Lost circulation ~ has not been a problem in the area and is not expected in this well. Lost circulation material will be on-hand at the rig if required. · Some tight hole has been noted while running casing, in particular with 13-3/8" casing in 16" hole. All Aurora wells on S-pad have experienced some degree of tight hole while drilling and casing the surface hole, though proper drilling and hole cleaning practice has ensured that the difficulty is minimal. · No faults are mapped in the direction of the well plan surface hole. · Heavy clays are reported in the 2000-3000' TVD area of S-pad. · Produced water injection has over-pressured the SV3/Cretaceous zone. Recent well S- %'~'"~% 40 required 9.3 ppg mud to drill this interval. INTERMEDIATE/PRODUCTION HOLE SECTIONS: · The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the 8-3/4" hole. The first three Aurora wells covered the SV1 sand with the surface casing to mitigate differential sticking hazards across the sand. Due to the Iow hole angle through the HRZ, a lower mud weight will be required to provide well bore stability, thus minimizing the risk of differential sticking. · The closest mapped fault is approximately 400' east of the planned target coordinate at the top of Kuparuk, following parallel to the plan trajectory to TD. Adequate standoff will be maintained to avoid fault-related lost circulation problems and seismic uncertainty (___100'). · Gas cut mud occurred in a relatively nearby well (S-03) at 5713' TVD. Mud weight was increased from 10.1 ppg to 10.3 ppg to handle the problem. All Aurora S-Pad wells drilled this year have contained oil at the top of the Ugnu. For this reason the 7" casing will be cemented to 500' above the UG4A. S-104i Permit to Drill Page 5 Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: . Rig 1. 2. 3. 4. 5'. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. If necessary, level the pad and prepare location for rig move. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Operations: MIRU Nabors 9ES. Nipple up diverter spool (with blinded outlet) and riser. PU 4" DP as required and stand back in derrick. MU 12 ¼" drilling assembly and drill surface hole to approximately 3726' MD / 2864' TVDbkb. The actual surface hole TD will be +/-100' TVD below the SV3 sand top (30' below the sand base). Run and cement the 9 5/8", 40# surface casing back to surface. A TAM port collar will be positioned at _+1000' as contingency in the event cement does no fully circulate to surface. ND diverter spool and riser and NU casing / tubing head. NU BOPE and test to 3500 psi. MU 8 3,~,, drilling assembly and RIH to float collar. Test the 9 5/8" casing to 3500 psi for 30 minutes. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a FIT to 12.5 ppg EMW. Drill per directional plan through the secondary target at the Schrader Bluff and to within 10' of the top of the Kuparuk reservoir sands. POH and change the BHA for an 8 Y2" core head with 90' core barrel. Change mud system to 4% KCI bland and core 90' through the Kuparuk C3B sand. RIH with 8 3,4" BHA, ream core interval and drill to TD at 150' below the base of Kuparuk A sands. TD: 9344' MD / 7183' TVDbkb. POOH. Wireline log the Kuparuk 3 runs. DP convey if necessary. Wiper trip the entire hole section. POH, standback 4" DP. Run 7" 26#/ft long string casing to TD and cement to 500' above the Ugnu UG4A formation in two stages, set on mandrel hanger. Displace cement with mud. Freeze protect 7" x 9-5/8" annulus with dead crude to 2000' TVD through 7" port collar. RIH with 6-1/8" cleanout assembly and drill DV stage collar and plugs. Cleanout to PBTD (_+80' from TD). Test casing to 3500 psi. Change well over to clean NaCI/KCI brine at 8.9 ppg for 100 psi overbalance at the top of the Schrader Bluff. 16. RU Schlumberger USIT log and log entire 7" casing to the top of cement above the Ugnu fg,~[on. Temporary Halt of Operations due to unavailability of completion equipment. Run 280' freeze protection string on tubing hanger and freeze protect well until operations resume in February, 2001. S-104i Permit to Drill Page 6 Upon resumption of operations, MIRU, circulate out diesel freeze protection, pull freeze protection string, and resume with step 17: 17. Perforate +200' of the Schrader interval to be located behind the straddle packers. Circulate, POH, LDDP. 18. Run 4 W', 12.6# L-80 multi-straddle selective completion string. See attached completion schematic for details. 19. Set production packers and test tubing to 5000 psi and annulus to 3500 psi. 20. Install two-way check and test to 3500 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 21. Pull two-way check and shear the RP valve. Freeze protect the tubing and annulus to 2000' TVD. 22. Install BPV. Secure the well and rig down / move off 9ES. Estimated Spud Date: 12/04/2000 Phil G. Smith Shared Services Drilling 564-4897 smithpgl @BP.com S-104i Permit to Drill Page 7 .,m,.,.,~- .?~.:~,~_~ AI~ O~li~ & Wells S-1~ WP~(~-2~) Single Wdl Tergm ~ far ~104 W~ (~-23) M~u~nt U~: C~I~ Tarot Nnl ~O ~ ~1~ ~s ~ ~ T~gM ~ Ty~ , S-104 ~upr 10~4 ~ ~nt ~9~.~ ~?~0.~ 4~3& I? N ~61~.~ W ~8~.~ N S-I~ Sc~9/l~ ~ Point ~l~.~ ~100,00 41~3.3~ N ~.17 W 5~84~0.~ N , . Ve~ O~: ~1~ W~ (~-1~) H~I O~n: ~I~ W~ N~ R~: T~ Ve~ ~n ~n: 0.~ N~,~ E 0.~ 0.~ O.~tO 0.~ 0.~ N ~.~ 0,~ 0.910 3~,~ ~.~ 3,~ 3~,1~ 4~.91 ~ ~ ~3.~ 3~,~ ~.~ N 371.~ W 333~ 0,~ ~,~ ~ ~j_~ ~1~.~ ~11,~ 26~ ~5.~ ~5~ ~ ! 7 N IGIZ~ w ~.~ o~ ~0.~ 26.~ ~5.~ 71~.13 · 4M~ N i~.1o w ~ o.~ ,. Cu~ Well Pre~ WeD: ~1~ WPB O 0 H~al ' ~1~ m e 2,~'/~:~.~MD. 4~.~fl ~ R~. O~h~l ~t~: 70° gl' ~,~S' N, ~IO' ~' 57.1814' RKB E~atbn: ~.~ ~ ~an Boa Le~t X IU~; Fe~ $~00 ......................~-- 4800 -- ................... ~~~~ ~ ~ ~ _ ,~ ~'~ . , { I I I ~le: l~h = 1~ Ve~ical Section S~n ~uth: ~7.016~ ~ No~h)' RECEIVED NOV 28 2000 Alaska Oil & Gas Cons. Commission ~nchoraoe North Slope Alaska Alaska Drilling & Wells PBU_ WOA S Pad S- 104 WPS (EX-23) - S- 104 Wp 07 PROPOSAL REPORT 17 November, 2000 Surface Coordinates: 5980849.97 N, 618930.01 E (70° 21' 22.8005" N, 210° 57' 57.1814" E) Kelly Bushing: 65.90ft above Mean Sea Level I~'1:! I~L L IIt I~; $;ERVII~ES Proposal Ref: pro 10596 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - S-104 Wp 07 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -65.90 0.00 100.00 0.000 0.000 34.10 100.00 200.00 0.000 0.000 134.10 200.00 300.00 0.000 0.000 234.10 300.00 400.00 1.500 354.193 500.00 3.000 354.193 600.00 5.000 354.193 650.00 6.000 354.193 334.09 434.01 533.76 583.53 633.18 731.94 700.00 7.500 354.193 800.00 10.500 354.193 399.99 499.91 599.66 649.43 699.08 797.84 900.00 13.500 354.193 829.74 895.64 1000.00 16.500 354.193 926.32 992.22 1100.00 19.500 354.193 1021.42 1087.32 1200.00 22.500 354.193 1114.77 1180.67 1300.00 25.500 354.193 1206.11 1272.01 1400.00 28.500 354.193 1295.20 1361.10 1500.00 31.500 354.193 1381.79 1447.69 1600.00 34.500 354.193 1465.65 1531.55 1700.00 37.500 354.193 1546.54 1612.44 1800.00 40.500 354.193 1624.25 1690.15 1900.00 43.500 354.193 1698.55 1992.52 46.276 354.193 1764.10 2000.00 46.537 354.178 1769.26 2045.36 48.123 354.089 1800.00 2100.00 50.034 353.987 1835.79 1764.45 1830.00 1835.16 1865.90 1901.69 Local Coordinates Global Coordinates Northlngs Eastlngs Northlngs Eastlngs (ft) (ft) (ft) (ft) 0.00N 0.00E 5980849.97 N 618930.01 E 0.00N 0.00 E 5980849.97 N 618930.01E 0.00N 0.00E 5980849.97 N 618930.01 E 0.00 N O.00E 5980849.97 N 618930.01 E 1.30 N 0.13W 5980851.27 N 618929.86 E 5.21N 0.53W 5980855.17 N 618929.40E 12.15 N 1.24W 5980862.10 N 618928.58 E 16.92 N 1.72W 5980866.86 N 618928.02 E 22.76 N 2.31W 5980872.69 N 618927.33 E 38.32 N 3.90W 5980888.23 N 618925.50 E 59.01N 6.00W 5980908.87 N 618923.07 E 84.75 N 8.62W 5980934.57 N 618920.05 E 115.49 N 11.75W 5980965.26 N 618916.43 E 151.14 N 15.37W 5981000.85 N 618912.24 E 191.60N 19.49W 5981041.24 N 618907.48 E 236.76 N 24.08W 5981086.32 N 618902.18 E 286.50 N 29.14W 5981135.97 N 618896.33 E 340.68 N 34.65W 5981190.05 N 618889.96 E 399.15 N 40.59W 5981248.42N 618883.09 E 461.75 N 46.96W 5981310.92 N 618875.73 E 528.31 N 53.73W 5981377.36 N 618867.90 E 593.27 N 60.33W 5981442.20 N 618860.26 E 598.65 N 60.88W 5981447.58 N 618859.63 E 631.83 N 64.29W 5981480.70 N 618855.69 E 672.89 N 68.58W 5981521.69 N 618850.75 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 1.50 1.50 2.00 2.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.50 3.50 3.50 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 0.00 0.00 0.00 0.00 1.25 5.00 11.67 16.24 21.86 36.80 56.66 81.39 110.91 145.14 184.00 227.37 275.13 327.16 383.31 443.43 507.35 569.73 574.90 606.78 646.25 Begin Dir @ 1.5.000°/100ft: 300.0Oft MD, 300.00ft TVD Continue Dir @ 2.000°/100ft: 500.00ft MD, 499.91fl TVD Continue Dir @ 3.000°/100ft: 650.00ft MD, 649.43fl TVD Continue Dir @ 3.500°/100ft: 1992.52ft MD, 1830.00ft TVD B Perm Continued... 17 November, 2000- 18:19 - 2- DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23)- S-104 Wp 07 North Slope Alaska Measured Depth (ft) Incl. Azlm. Sub-Sea Depth (ft) Vertical Depth (ft) 2200.00 53.532 353.814 1897.64 1963.54 2208.93 53.844 353.799 1902.93 1968.83 2300.00 53.844 353.799 1956.66 2022.56 2400.00 53.844 353.799 2015.66 2081.56 2500.00 53.844 353.799 2074.66 2140.56 2600.00 53.844 353.799 2133.66 2199.56 2700.00 53.844 353.799 2192.66 2258.56 2800.00 53.844 353.799 2251.65 2317.55 2900.00 53.844 353.799 2310.65 2376.55 3000.00 53.844 353.799 2369.65 2435.55 3100.00 53.844 353.799 2428.65 2494.55 3200.00 53.844 353.799 2487.65 2553.55 3300.00 53.844 353.799 2546.65 2612.55 3400.00 53.844 353.799 2605.65 2671.55 3500.00 53.844 353.799 2664.65 2730.55 3563.31 53.844 353.799 2702.00 2767.90 3600.00 53.844 353.799 2723.64 2789.54 3700.00 53.844 353.799 2782.64 2848.54 3732.81 53.844 353.799 2802.00 2867.90 3800.00 53.844 353.799 2841.64 2907.54 3900.00 53.844 353.799 2900.64 2966.54 4000.00 53.844 353.799 2959.64 3025.54 4100.00 53.844 353,799 3018.64 3084.54 4200.00 53.844 353.799 3077.64 3143.54 4300.00 53.844 353.799 3136.64 3202.54 Local Coordinates Global Coordinates Northings Eastlngs Northlngs Eastings (ft) (ft) (ft) (ft) 751.00 N 76.93 W 5981599.65 N 618841.16 E 758.15 N 77.71 W 5981606.79 N 616840.28 E 831.25 N 85.65 W 5981679.76 N 618831.1 7 E 911.52 N 94.37 W 5981759.88 N 618821.18 E 991.79 N 103.09 W 5981840.00 N 618811.19 E 1072.06 N 111.81W 5981920.12 N 618801.19 E 1152.33 N 120.53W 5982000.24 N 618791.20 E 1232.60 N 129.25W 5982080.36 N 618781.20 E 1312.87 N 137.97W 5982160.48N 618771.21E 1393.14 N 146.70W 5982240.60 N 618761.22 E 1473.41N 155.42W 5982320.72 N 618751.22 E 1553.67 N 164.14W 5982400.84 N 618741.23 E 1633.94 N 172.86W 5982480.96 N 618731,23 E 1714.21N 181.58W 5982561.08 N 618721.24 E 1794.48N 190.30W 5982641.20 N 618711.25 E 1845.30 N 195.82W 5982691.93N 618704.92E 1874.75 N 199.02W 5982721.32 N 618701.25 E 1955.02N 207.74W 5982801.44N 618691.26 E 1981.36 N 210.60W 5982827.73 N 618687.98 E 2035.29 N 216.46W 5982881.57 N 618681.26 E 2115.56 N 225.18W 5982961.69 N 618671.27 E 2195.83 N 233.90W 5983041.81N 618661.28 E 2276.09 N 242.62W 5983121.93 N 618651.28 E 2356.36 N 251.34W 5983202.05 N 618641.29 E 2436.63 N 260.06W 5983282.17 N 618631.29 E Dogleg Rate (°/100ft) 3.50 3.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 721.42 728.31 798.71 876.01 953.31 1030.61 1107.92 1185.22 1262.52 1339.82 1417.12 1494.43 1571.73 1 649.03 1726.33 1775.27 1803.63 1680.93 1906.30 1958.24 2035.54 2112.84 2190.14 2267.44 2344.75 SV3 9 5/8" Casing Continued... 17 November, 2000 - 18:19 - 3 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - S-104 Wp 07 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4398.92 53.844 353.799 3195.00 3260.90 4400.00 53.844 353.799 3195.63 3261.53 4500.00 53.844 353.799 3254.63 3320.53 4600.00 53.844 353.799 3313.63 3379.53 4700.00 53.844 353.799 3372.63 3438.53 4300.00 53.844 353.799 3431.63 3497.53 4900.00 53.844 353.799 3490.63 3556.53 5000.00 53.844 353.799 3549.63 3615.53 5063.34 53.844 353.799 3587.00 3652.90 5100.00 53.844 353.799 3608.63 3674.53 5200.00 53.844 353.799 3667.62 3733.52 5300.00 53.844 353.799 3726.62 3792.52 5400.00 53.844 353.799 3785.62 3851.52 5500.00 53.844 353.799 3844.62 3910.52 5577.87 53.844 353.799 3890.56 3956.46 5578.09 53.844 353.799 3890.69 3956.59 5600.00 53.203 353.275 3903.72 3969.62 5700.00 50.310 350.766 3965.62 4031.52 5800.00 47.476 348.040 4031.36 4097.26 5900.00 44.712 345.058 4100.71 4166.61 6000.00 42.034 341.775 4173.41 4239.31 6100.00 39.460 338.140 4249.17 4315.07 6200.00 37.011 334.097 4327.72 4393.62 6300.00 34.716 329.584 4408.77 4474.67 6400.00 32.607 324.541 4492.02 4557.92 Local Coordinates Global Coordinates Northlngs Eastings Northlngs Eastlngs (~) (~) (~t) (ft) 2516.04N 268.69W 5983361.42N 618621.41E 2516.90N 268.79W 5983362.29 N 618621.30E 2597.17 N 277.51W 5963442.41N 618611.31E 2677.44N 286.23W 5983522.53N 618601.31 E 2757.71 N 294.95W 5983602.65 N 618591.32 E 2837.98 N 303.67W 5983682.77 N 618581.32 E 2918.25 N 312.39W 5963762.89 N 618571.33 E 2998.51N 321.11W 5983843.01N 618561.34 E 3049.36 N 326.63W 5983893.76N 618555.01 E 3078.78 N 329.83W 5983923.13 N 618551.34 E 3159.05 N 338.55W 5984003.25 N 618541.35 E 3239.32 N 347.27W 5984083.37 N 618531.35 E 3319.59 N 355.99W 5984163.49 N 618521.36 E 3399.86 N 364.71W 5984243.61N 618511.37 E 3462.36 N 371.50W 5984306.00N 618503.58 E 3462.54N 371.52W 5984306.18 N 618503.56 E 3480.05 N 373.51W 5984323.65 N 618501.30 E 3557.81 N 384.37W 5984401.23 N 618489.20 E 3631.86 N 398.19W 5984475.05 N 618474.21 E 3701.92 N 414.90W 5984544.84 N 618456.39 E 3767.73 N 434.44W 5984610.33 N 618435.80 E 3829.04 N 456.75W 5984671.27 N 618412.52 E 3885.62 N 481.74W 5984727.46N 618386.64 E 3937.27 N 509.32W 5984778.66 N 618358.25 E 3983.79 N 539.37W 5984824.69 N 618327.46E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 2421.22 2422.05 2499.35 2576.65 2653.95 2731.26 2808.56 2885.86 2934.82 2963.16 3040.46 3117.76 3195.07 3272.37 3332.56 3332.73 3349.62 3425.46 3499.02 3570.05 3638.26 3703.42 3765.27 3823.58 3878.14 SVl ( Top Ugn~UG4A Begin Dir @ 3.5.000°/100ff: 5577.87ft MD, 3956.46ft TVD Continued... 17 November, 2000 - 18:19 - 4 - DrillQuest 2,00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - S-104 Wp 07 North Slope Alaska Measured Depth (~t) incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6500.00 30.724 318.918 4577.14 4643.00 6600.00 29.109 312.687 4663.84 4729.74 6686.67 27.965 306.803 4740.00 4605.90 6700.00 27.812 305.861 4751.77 4817.67 6800.00 26.877 298.513 4640.63 4906.53 6900.00 26.344 290.785 4930.06 4995.96 6933.39 26.261 288.154 4960.00 5025.90 7000.00 26.238 282.882 5019.74 5085.64 7044.89 26.331 279.340 5060.00 5125.90 7089.56 26.509 275.849 5100.00 5165.90 7100.00 26.509 275.849 5109.34 5175.24 7200.00 26.509 275.849 5198.83 5264.73 7300.00 26.509 275.849 5288.32 5354.22 7335.41 26.509 275.849 5320.00 5385.90 7400.00 26.509 275.849 5377.80 5443.70 7500.00 26.509 275.849 5467.29 5533.19 7600.00 26.509 275.849 5556.77 5622.67 7700.00 26.509 275.849 5646.26 5712.16 7800.00 26.509 275.849 5735.75 5801.65 7900.00 26.509 275.849 5825.23 5891.13 8000.00 26.509 275.849 5914.72 5980.62 8100.00 26.509 275.849 6004.20 6070.10 8200.00 26.509 275.849 6093.69 6159.59 8300.00 26.509 275.849 6183.18 6249.08 8400.00 26.509 275.849 6272.66 6338.56 Local Coordinates Global Coordinates Northlngs Eastings Northings Eastlngs (ft) (ft) (tt) (ft) 4025.00N 571.80W 5984865.39 N 618294.38 E 4060.76 N 606.48W 5984900.59 N 618259.14 E 4087.24 N 638.25W 5984926.56 N 618226.95 E 4090.93 N 643.27W 5984930.17 N 618221.87 E 4115.39 N 682.06W 5984954.02 N 618182.70 E 4134.06N 722.67W 5984972.04N 618141.79 E 4138.99 N 736.62W 5984976.75 N 618127.77 E 4146.87 N 764.98W 5984984.17 N 618099.29 E 4150.70N 784.48W 5984987.69 N 618079.73 E 4153.32 N 804.17W 5984990.00N 618060.00 E 4153.80 N 808.81W 5984990.40N 618055.36 E 4158.34 N 853.21W 5984994.24 N 618010.89 E 4162.89 N 897.61W 5984998.09 N 617966.42 E 4164.50 N 913.33W 5984999.45 N 617950.67 E 4167.44N 942.01W 5985001.93N 617921.95 E 4171.99 N 986.42W 5985005.77 N 617877.48E 4176.54 N 1030.82W 5985009.62 N 617833.01 E 4181.09 N 1075.22W 5985013.46 N 617788.54 E 4185.63 N 1119.62W 5985017.30 N 617744.08 E 4190.18 N 1164.03W 5985021.14 N 617699.61 E 4194.73 N 1208.43W 5985024.99 N 617655.14 E 4199.28 N 1252.83W 5985028.83 N 617610.67 E 4203.83 N 1297.23W 5985032.67 N 617566.20 E 4208.38 N 1341.63W 5985036.52 N 617521.73 E 4212.93 N 1386.00W 5985040.36 N 617477.26 E Dogleg Rate (°/lOOft) 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 3928.75 3975.21 4011.99 4017.35 4055.01 4088.06 4098.05 4116.37 4127.51 4137.61 4139.86 4161.39 4182.91 4190.53 4204.44 4225.96 4247.49 4269.01 4290.54 4312.06 4333.59 4355.11 4376.64 4398.16 4419.69 Top Schrader/MB1 WS2/Schrader Na WSl/Scharder Oa End Dir: 7089.41ft MD, 5165.77ft TVD Target - S-104 Schrader 9/12, Geological Base West Sak/Obf Continued... 17 November, 2000- 18:19 - 5- DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - S-104 Wp 07 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8500.00 26.509 275.849 6362.15 6428.05 8600.00 26.509 275.649 6451.63 6517.53 8700.00 26.509 275.649 6541.12 6607.02 8700.98 26.509 275.649 6542.00 6607.90 8800.00 26.509 275.649 6630.61 6696.51 8876.43 26.509 275.849 6699.00 6764.90 8895.42 26.509 275.649 6716.00 6781.90 8900.00 26.509 275.849 6720.09 6785.99 8911.07 26.509 275.849 6730.00 6795.90 8923.36 26.509 275.849 6741.00 6806.90 9000.00 26.509 275.849 6809.58 6875.48 9012.77 26.509 275.849 6821.00 6886.90 9027.29 26.509 275.849 6834.00 6899.90 9048.52 26.509 275.849 6853.00 6918.90 9100.00 26.509 275.849 6899.07 6964.97 9116.69 26.509 275.849 6914.00 6979.90 9189.32 26.509 275.849 6979.00 7044.90 9200.00 26.509 275.849 6988.55 7054.45 9300.00 26.509 275.849 7078.04 7143.94 9343.80 26.509 275.849 7117.23 7183.13 Local Coordinates Global Coordinates Northings Eastlngs Northings Eastings (ft) (ft) (ft) (ft) 4217.47 N 1430.44 W 5985044.20 N 617432.79 E 4222.02 N 1474.84 W 5985048.04 N 617388.33 E 4226.57 N 1519.24 W 5985051.89 N 617343.86 E 4226.61 N 1519.68 W 5985051.93 N 617343.42 E 4231.12 N 1563.64 W 5985055.73 N 617299.39 E 4234.59N 1597.58W 5985058.67 N 617265.40 E 4235.46N 1606.01W 5985059.40N 617256.95 E 4235.67N 1608.05W 5985059.57 N 617254.92 E 4236.17 N 1612.96W 5985060.00N 617250.00 E 4236.73 N 1618.42 W 5985060.47 N 617244.53 E 4240.22 N 1652.45W 5985063.42N 617210.45 E 4240.80 N 1658.12W 5985063.91N 617204.77 E 4241.46N 1664.57W 5985064.47N 617198.31 E 4242.42 N 1673.99W 5985065.28 N 617188.87 E 4244.76N 1696.85W 5985067.26N 617165.98 E 4245.52N 1704.26W 5985067.90N 617158.56 E 4248.83N 1736.51W 5985070.69 N 617126.26 E 4249.31N 1741.25W 5985071.10 N 617121.51E 4253.86N 1785.65W 5985074.95 N 617077.04 E 4255.85 N 1805.10W 5985076.63N 617057.57 E Dogleg Rate (o/10ott) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 4441.21 4462.74 4484.26 4484.48 4505.79 4522.24 4526.33 4527.31 4529.70 4532.34 4548.84 4551.59 4554.71 4559.28 4570.36 4573.96 4589.59 4591.89 4513.42 4522.84 THRZ BHRZ C4B C4A Target - S-104 Kupr 10/24, Geological C3B C2 C1 B/LCU A6 Miluveach Total Depth: 9343.80ft MD, 7183.13ft TVD 7" Casing Continued... 17 November, 2000 - 18:19 - 6 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - S-104 Wp 07 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-104 WPS (EX-13). Northings and Eastings are relative to S-104 WPS (EX-13). The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from S-104 WPS (EX-13) and calculated along an Azimuth of 337.016° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9343.80ft., The Bottom Hole Displacement is 4622.84ft., in the Direction of 337.016° (True). Comments Measured Station Coordinates Depth TVD Northings Eastlngs (fi) (ft) (fi) (ft) 300.00 300.00 0.00 N 0.00 E 500.00 499.91 5.21 N 0.53 W 650.00 649.43 16.92 N 1.72 W 1992.52 1830.00 593.26 N 60.33 W 5577.87 3956.46 3462.36 N 371.50 W 7089.56 5165.90 4153.32 N 804.17 W 9343.80 7183.13 4255.85 N 1805.10 W Comment Begin Dir @ 1.5.000°/100ft: 300.00It MD, 300.00ft TVD Continue Dir @ 2.000°/100ft: 500.00ft MD, 499.91ft TVD Continue Dir @ 3.000°/100ft: 650.0Oft MD, 649.43ft TVD Continue Dir @ 3.500°/100ft: 1992.52ft MD, 1830.00ft TVD Begin Dir @ 3.5.000°/100ft: 5577.87ft MD, 3956.46ft TVD End Dir: 7089.41ft MD, 5165.77ft TVD Total Depth' 9343.80ft MD, 7183.13ft TVD Continued... 17 November, 2000 - 18:19 - 7- DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - S-104 Wp 07 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip DIr. (fi) Deg. Deg. 1800.00 0.000 0.910 2702.00 0.000 0.910 3195.00 0.000 0.910 3587.00 0.000 0.910 4740.00 0.000 0.910 Profile Measured Vertical Depth Depth (fi) (ft) Penetration Point Sub-Sea Depth Northings Eaatings (fi) (fi) (ft) 2045.36 1865.90 1800.00 631.83 N 64.29 W 3563.31 2767.90 2702.00 1845.30 N 195.82 W 4398.92 3260.90 3195.00 2516.04 N 268.69 W 5063.34 3652.90 3587.00 3049.36 N 326.63 W 6686.67 4805.90 4740.00 4087.24 N 638.25 W 4960.00 0.000 0.910 6933.39 5025.90 5060.00 0.000 0.910 7044.89 5125.90 5320.00 0.000 0.910 7335.41 5385.90 6542.00 0.000 0.910 8700.98 6607.90 6699.00 0.000 0.910 8876.43 6764.90 6716.00 0.000 0.910 8895.42 6781.90 6730.00 0.000 0.910 8911.07 6795.90 6741.00 0.000 0.910 8923.36 6808.90 6821.00 0.000 0.910 9012.77 6886.90 6834.00 0.000 0.910 9027.29 6899.90 6853.00 0.000 0.910 9048.52 6918.90 6914.00 0.000 0.910 9116.69 6979.90 6979.00 0.000 0.910 9189.32 7044.90 Formation Name B Perm SV3 SVl Top Ugnu/UG4A Top Schrader/MB1 4960.00 4138.99 N 738.62 W WS2/Schrader Na 5060.00 4150.70 N 784.48 W WS1/Scharder Oa 5320.00 4164.50 N 913.33 W Base West SaldObf 6542.00 4226.61 N 1519.68 W THRZ 6699.00 4234.59 N 1597.58 W BHRZ 6716.00 4235.46 N 1608.01 W C4B 6730.00 4236.17 N 1612.96 W C4A 6741.00 4236.73 N 1618.42 W C3B 6821.00 4240.80 N 1658.12 W C2 6834.00 4241.46 N 1664.57 W C1 6853.00 4242.42 N 1673.99 W 6914.00 4245.52 N 1704.26 W 6979.00 4248.83 N 1736.51 W B/LCU A6 Miluveach Continued... 17 November, 2000 - 18:19 - 8 - DrillQuest 2.00.05 Sperry-Sun Drilling Services Proposal Report for S-104 WPS (EX-23) - $-104 Wp 07 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> <Surface> <Surface> Casing Detail 3732.81 2867.90 9 5/8" Casing 9343.80 7183.13 7" Casing Targets associated with this wellpath Target Name S-104 Kupr 10/24 S-104 Schrader 9/12 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry TVD (ft) 6795.90 6730.00 5165.90 5100.00 Coordinates Northlngs Eaatlnga (ft) (ft) Target Target Shape Type 4236.17 N 1612.96 W Point 5985060.00 N 617250.00 E 70° 22' 04.4645" N 210° 57' 09.9989" E 4153.32 N 804.17 W Point 5984990.00 N 618060.00 E 70° 22' 03.6509" N 210° 57' 33.6580" E Geological Geological 17 November, 2000 - 18:19 - 9- DrillQuest 2.00.05 30O/ 27C 24(}\ --15.9 15.0 12.5 10.0 7.5 5.0 2.5 --0 2.5 5.0 7.5 10.0 12.5 15.0 --15,9 -t5:.~ ~--.~ct~ Froln Colour To MD ~ u 500 15.0 ~ 500 ~'-'~'~--' 1000 ~ 1000 2000 ~ 2000 3000 12.5 x 3000 -- 4000 N 4000 5000 x 5000 "'~-' 7500 7500 10000 l 00 t 0000 50000 7.5 5.0 2.5 j90 120 High Side + Ref, Azinmth [deg] vs Centre to Centre Separation [5fV'inl Sperry-Sun Anficoilision Report Company: BP ~o~o : Field: Prudhoe Bay Reference Site: PBS Pad Reference Well: S-104 (Slot 23) Reference Wellpa~: S-104 :-: Co~°~Ref~: .'.'..- .Welii:.S~104 (SlOt 23),'.TrueNorth ." ':: ¥~('I'~D) Refe~enee~ "'." -S-100Wps 66.0. ' .... : ' ~ :::: ': :: : ':::: :: .... ''. ' ' " 'Db: ·Oracle / GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are 'rl~l~mlls in this liL~ll~: S-104 WP-07 & NOT PLANNED P~ Interpolation Method: MD lntervnl: 50.000 ff Error Model: ISCWSA Ellipse l Depth Eaage: 30.000 to 9343.600 ft ~ Me.od: High Side + Azimuth MaximumRadlus: 1131.360 ft ErrorSarface: Ellipse+Casing Casing Points ft 4611.386 3386.000 7.750 8.500 7 5/8" 8733.000 6636.213 4.500 6.000 4 1/2" Plan: S-104 WP-07 Date Composed: 11/10/2000 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Summary <. OffsetWellpam " , .> :: ~. :'i:--': ~'i~Refe. re~e:!:!:Ol~t '-:.":" ;~;CU'.:;:No-Go'~'...'.AliOWable' :.......:../ '..:..'.. :...' .....'.. we. w.n~m :. ~: .~i~-~i~i~.~::~:..:..:.:.::.~:~.=.~.......~:.:.:~.~~..::.~..:..:~:.:.~`~...::.....: ~iwa~''. :..'.'...": ': : /i:::~:~;:: , :i:~:.':' :~ft ....-:."' "~: ""ff.--:' ~'.: .:?/:"'"fi'. :".-.::'::-""~:ff:.i :. '.- :'.-'-'ft ::. ;'." ,:.: ....... ::.':""~. :': ":. "'.'..' : ' :: : :: :::;~'~: ~:. ~-:~.........: ... .. ... ~ .:. . . ~ -: .......- ... _......:- · . ..... .. . .. . ... Site PBS Pad planning Plan: Exp Slot 13 Plan: S-213 V0 Plan: PBS Pad S-100 S-100 V9 PBS Pad S-101 PBS Pad S-101 PBS Pad S-102 PBS Pad S-102 PBS Pad $-103 PBS Pad S-105 (Slot22) PBS Pad S-201 PBS Pad S-23 348.410 350.000 150.299 5.764 144.535 Pass: Major Risk 537.713 550.000 209.764 8.876 200.881 Pass:Major Risk S-101 V2 201.576 200.000 226.894 3.727 223.167 Pass: Major Risk S-101PB1 V9 201.576 200.000 226.894 3.852 223.042 Pass: Major Risk S-102 pbl Vll 492.201 500.000 188.454 8.285 180.183 Pass: Major Risk S-102 V2 492.201 500.000 188.454 8.160 180.308 Pass: Major Risk S-103 Vl Plan: S-103 W 349.039 350.000 75.505 5.765 69.741 Pass: Major Risk S-105 V4 415.590 350.000 13.514 6.474 7.043 Pass: Major Risk PLAN S-201 V6 Plan: S- 349.328 350.000 50.296 7.300 52.997 Pass: Major Risk S-23 V1 341.459 350.000 1011.467 5.557 1005.910 Pass: Major Risk Site: PBS Pad planning Well: Plan: Exp Slot 13 Rule Assigned: Major Risk Wellpath: Plan: S-213 V0 Plan: Plan 01 Vl later-Site Error: 0.000 ft . ::: :: ~::~:.- ~ :::::::::::::::::::::::: :?::~ ~.-:~::?.-~/:.~:~.%~::~:-~:.:~_:.:~:~:~.%~:..~:~ ~ ~.~ ~.~ 65.7~ 65.7~ 0.0~ 0.~ 1~.92 1~.~ 8.~ 140.9~ 1.1~ 148.~3 1~.~ 1~.~ 1~.~ 1~.~ 0.~ 0.01g 1~.92 1~.~ 8.~ 149.9~ 1.588 148.394 Pa~ 1~.3~ 1~.~ 1~.~ 1~.~ 0.~ 0.094 1~.~ 1~.~ 8.~ 149.9~ 2.481 147.~1 2~.3~ 2~.~ 2~.~ 2~.~ 0.152 0.132 1~.92 1~.~ 8.~ 149.0~ 3.262 1~.7~ 2~.3~ 2~.~ 2~.~ 2~.~ 0.208 0.1~ 1~.92 1~.~ 8.~ 149.9~ 4.124 145.8~ 300.000 300.000 300.000 300.000 0.264 0.244 180.92 180.92 8.500 149.983 4.933 145.050 Pass 348.410 348.408 350.000 350.000 0.318 0.306 180.91 186.71 8.500 150.299 5.764 144.535 Pass 396.515 396.505 400.000 4(X).000 0.372 0.357 180.86 186.67 8.500 151.241 6.561 144.680 Pass 444.590 444.555 450.000 450.000 0.427 0.418 180.80 186.60 8.500 152.808 7.389 145.420 Pass 492.619 492.537 500.000 500.000 0.482 0.472 180.70 186.51 8.500 155.000 8.193 146.808 Pass 540.060 539.898 550.000 550.000 0.541 0.532 150.58 186.39 8.5(X) 157.887 9.030 148.861 Pass 587.303 587.009 600.0(X) 600.000 0.501 0.587 180.44 186.24 8.5(X) 161.590 9.831 151.788 Pass 634.418 633.928 650.000 650.0(X) 0.667 0.647 180.27 186.07 8.500 166.111 10.677 155.491 Pass 680.520 679.755 700.000 700.(XX) 0.739 0.702 180.07 185.88 8.500 171.528 11.518 160.123 Pass 725.946 724.781 750.000 750.000 0.824 0.763 179.85 185.66 8.500 178.106 12.406 165.907 Pass 771.059 769.343 800.000 800.000 0.915 0.818 179.62 185.43 8.500 185.853 13.294 172.878 Pass 815.803 813.365 850.000 849.999 1.016 0.828 179.43 185.24 8.500 194.829 14.080 181.217 Pass 860.118 856.768 900.000 899.995 1.136 0.839 179.35 185.15 8.500 205.089 14.902 190.640 Pass 900.000 895.642 950.000 949.983 1.243 0.816 179.35 185.16 8.500 216.651 15.552 201.926 Pass 947.260 941.455 1000.000 999.959 1.406 0.796 179.43 185.24 8.500 229.374 16.418 214.057 Pass 989.996 982.624 1050.000 1049.921 1.553 0.794 179.58 185.39 8.500 243.357 17.239 227.456 Pass 1032.119 1022.941 1100.000 1099.863 1.724 0.792 179.78 185.59 8.500 258.537 18.153 242.048 Pass 1073.593 1062.365 1150.000 1149.782 1.899 0.804 180.03 185.83 8.500 274.889 19.073 257.778 Pass 1114.385 1100.859 1200.000 1199.675 2.083 0.816 180.30 186.11 8.500 292.391 20.052 274.660 Pass 1154.438 1138.367 1250.000 1249.529 2.285 0.841 180.61 186.42 8.500 311.088 21.0.53 292.701 Pass ~RAM WELLHEAD-- FMC 11" A CTUA TOR= KB. ELEV = 64.5 BF. ELEV = 35.9 KOP -- 300' Max Angle = 54 @ 2200 Datum MD = Datum TV D: 9-5~8" 40# L-80 BTC 3726' Minimum ID -- 2.750" @ X nipple[ S-104i SAFETY NOTES: ACTUAL DEPTHS WILL BE PROVIDED BEFORE COMPLETION 2100' I [ X-Nipple, 3.813" ID [ STA MD 'rVD I DEV I TYPE MAN LATCH I I GLM5 -4900 3500 GLM4 -6775 2 jts above top packer GLM3 6940 BPL3 7000 GLM2 7100 BPL2 7200 GLM1 7500 BPL1 7600 ,6860' [ ] 4-1/2" X, 3.813" ID [ __1688o' I ! I --'7020' I I I '--~t7380' I I I [ ~-~,, ~.~#~, ~-ao [ 87oo' [ NSCT ~ PERFORATION SUMMARY REF LOG: ANGLE ATTOP PERF: I I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 8700, I [ BakerSABL3 I 8720' [ I 4-1/2" x 3-1/2" xo [ 8740' I I 3-1/2" X, 2.750" ID [ 8760' [ I 3-1/2" x, 2.750" ID [ ,8775' I I~''2" ~v'~ I~'~ I r 9260' I I ~'' ~#'--~°"n-'~'rc I I 9344' DATE REV BY COMMENTS PRUDHOE BAY UNIT / AURORA FIELD 11/14/00 P. Smith Original Proposed Completion WELL: S-104i APt No: Sec. 35, T12N, R12E, 4494' FEL, 633' FNL BP Exploration (Alaska) S-104i Ri_qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Monitor closely for signs of gas in the surface hole and perform regular evacuation drills. No gas has been encountered so far in the Aurora development and none is expected, however without the diverter on this well the consequence of encountering shallow makes reaction time more critical for personnel safety. High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. Previous Aurora S-Pad surface holes were drilled with 9.6- 9.7 pgg mud weight without problem. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 did not encounter any shallow gas problems. S-102 encountered hydrate shows at 2700' and 2850' TVDbkb, however there were no associated complications. Lost circulation while drilling has not been a problem so far in the Aurora development, despite several fault crossings. The closest known fault is 600' from the well plan near the top of the Kuparuk on S-105, converging to 300' from the plan at TD; lost circulation is not considered a likely hazard. Pipe sticking tendency can be mitigated through short trips in the Ugnu / West Sak area and by NOT backreaming connections. Ream down with reduced pump rates. The Ugnu interval can be expected to contain hydrocarbons. Directional work begins at 300' where a close approach exists. Maintain planned standoff from existing wells and monitor the direction closely. pad is not a designated H2S pad. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Aurora S-104i Hazards and Contingencies Page ! of 1 S-104 Kick Tolerance'-- i !/17/2000 3:53 PM $- 104i <== Data Input Phil Smith <== Data Input Mud Weight (ppg) 10.50 For Well Plans: Mud Wt. = Zone of interest pore pressure Weak point - Measured depth (ft) Weak point - True vertical depth (ft) Weak point - Hole angle (deg) Weak point - Hole size (in) Weak point pressure - EMW (ppg) 3,726' 2,864' 54.0° 8.750" 12.50 Zone of interest - Measured depth (ft) Zone of interest - True vertical depth (ft) Zone of interest - Hole angle (deg) Zone of interest - Hole size (in) Zone of interest - Pore pressure EMW (ppg) 8,910' 6,800' 26.0° 8.750" 9.90 Gas gradient (psi/fi) 0.10 Bottom hole assembly OD (in) Bottom hole assembly length (ft) Drill pipe OD (in) 6.750" 200' 4.000" BHA annular vol. @ zone of interest (bbl/ft) DP annular vol. @ zone of interest (bbl/ft) DP annular vol. @ weak point (bbl/ft) 0,0301 0.0588 0,0588 Additional safety margin (psi) <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input <== Data Input 0.00 <== Data Input Weak point pressure (psi): Plo 1,862 psi Weak point pressure - Safety margin: Pmax 1,862 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi): Pf 3,501 psi Weak Pt to Zone of Interest distance (TVD ft): OH {TVD} 3,936' Weak Pt to Zone of Interest distance (MD ft): OH {MD} 5,184' Maximum influx height at the bit (TVD ft): H {TVD} 1,144' Maximum influx height at the bit (MD fi): H {MD} 1,272' Calc. volume of (H} around BHA: Calc. volume of {H} around drill pipe: Vlbha 6.0 bbl Vldp 63.1 bbl Calc. volume that H equals @ initial shut in: V1 69.1 bbl Calc. vol. that H equals @ weak point (MD fi): Vwp 114.5 bbl Calc. volume of Vwp @ initial shut in: V2 60.9 bbl Kick Tolerance: V2 60.9 bbl Initial SICP which equals the Weak Point Pressure: NOTE: Spreadsheet Created by: G. S. Walz 11/22/94 298 psi r'HE A1TACHED CHECK IS IN PAYMENT FOR ITEMS D~.~R~F.D ABOVE. lOQ. oo P~Y 120 DAYS WELL PERMIT CHECKLIST COMPANY INIT CLASS FIELD & POOL ~ ~./Z~ ADMINISTRATION 1. Permit fee attached ...... -' ~' ~'-~"; ~i,~'.,' z;D'--'~i~'/ 2. Lease number appropriat~:-r-~. 't~. '.~J~.., ...... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... WELL NAME,~-//...~ ~"~.' PROGRAM: exp _dev __ redrll __ serv ~'" wellbore sag ann. disposal para req __ GEOL AREA ~..~ UNIT# ~ //~,~"d"~ ON/OFF SHORE Y N DATE A,_~/Z~'~/-~ ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... -Y---N 22. Adequate wellbore separation proposed ....... ' ...... .[:.~.t,,~\,¢,,c,~"~:~ 23. If diverter required, does it meet regulations .......... {~) N ~")~,,~e_~.~ ,~'t,~.~ ~'~e.,.,,.~,~e.~ ~,.~O~,'~e.~ ~,~---~'~.~, ~"[ ~'~ 'L-"~ ~\~t~t~,~,, 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ &tiZPJ~ DATE 26. BOPE press rating appropriate; test to '~.~L.~ psig. ~ N ~1~...~ e.~.~-~ ~_~.~O ,,]"~(o...% ~ ' ~ i~/.~.3 ' 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N ~ ,.. . ~ . 28. Work will occur without operation shutdown ........... ~ _bi.. ['4.tr~ ~,~zc~.~.~\ ~e.,~.~ "~ ~ ~.(:t.t,,,..%~;-%,~ ~,.~'~,.~, 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide mea.sur_~.~i~ .... y(/'~' ~..~,,~ /~ ,~/'~/'~ ~ ~ ~ /~_~_¢,--7 ~ ~.¢~ ,.~ -/'~_~z'~_//~/ 31. Da!a p. resented, on potent,al overpressure zone'~ ..... 32. Se~sm,c analys,s of shallow gas zones ............. .. zj...b~ N ~,,?..A. ~=,_~_,/~,_.~ ~ ~;Ac-tC-/.~z~-,,5,~ ~--¢,c~. ,>-A.. ~.-.~.,..~ · ' ' r~ DATE~ 33. Seabed cond,t, on survey (,f off-shore) ..... ...... ~..-¢'. / /[ ~-~-q ~ 34. Contact name/phone for weekly progress reports [exple~tory only] Y N ~ LA R DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) Will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: t~'c~° ~'~ Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11101fl00) 1:3 O Z O -I Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding informatiOn, information, of this. nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically.',. .. organize this category of information. S-104.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Feb 01 16:23:38 2002 Reel Header Service name ............. LISTPE Date ..................... 02/02/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 02/02/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay (Aurora) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10014 J. SACK T. ANGLEN S-104i 500292298800 BP Exploration, Inc. Sperry Sun 01-FEB-02 MWD RUN 2 AK-MM-10014 P. ROGER T. ANGLEN MWD RUN 3 AK-MM-10014 P. ROGER T. ANGLEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 4 AK-MM-10014 S. HUIBAN D. WILLIAMS MAD RUN 4 AK-MM-10014 S. HUIBAN D. WILLIAMS 35 12N 12E 4646 4494 .00 64.50 35.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 3735.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING Page 1 REMARKS: S-104.tapx ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). MWD RUNS 1-2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MULLER TUBE DETECTORS. 4. MWD RUNS 3-4 ARE DIRECTIONAL WITH DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. THE INTERVAL FROM 8765' MD TO 8934' MD WAS CORED FOLLOWING RUN 3. FORMATION DATA FOR THAT INTERVAL WERE ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE FOLLOWING MWD RUN 4. 6. DIGITAL DATA ARE DEPTH SHIFTED TO THE AIT GAMMA RAY LOGGED BY SCHLUMBERGER ON 27-JAN-01, PER THE E-MAIL OF 2/06/2001 FROM D. DOUGLAS OF BP EXPLORATION (ALASKA) INC. ALL HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4 REPRESENT THE MWD DATA FOR WELL S-104 WITH API% 50-029-2298'8-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9196' MD, 7159' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME M SUFFIX DENOTES MAD PASS $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPM FET RPS RPD .5000 START DEPTH 159 5 232 0 3701 0 3701 0 3701 0 3701 0 STOP DEPTH 9188 0 9201 0 9180 5 9180 5 9180 5 9180 5 Page 2 S-104.tapx RPX 3701.0 9180.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 161 5 3634 5 3667 5 3738 5 3780 5 3792 5 3814 0 3843 0 3872 0 4040 0 4120.5 4259.0 4321.5 4343.5 4421.5 4439.0 4548.5 4607.0 4731 0 4753 0 4779 5 4789 0 4801 0 4807 5 4812 0 4815 5 4820 0 4824 5 4860 0 4922 0 4939 0 4988 0 4991 5 5007 5 5064 0 5111 5 5130 5 5159 0 5191 5 5227 0 5250 5 5269 5 5294 0 5353 5 5358 5 5366.5 5380 5 5444 0 5473 0 5487 5 5508 0 5530 0 5540 5 5547 5 5560 5 5575 0 5594 5 5776.5 5793.0 5835.0 5863.5 5963.0 5997.5 6221.0 6274.0 6337.5 6343.5 GR 160. 3633 3667 3737 3780 3792 3814 3843 3872 4038 4118 4257 4319 4340 4420 4438 4547 4606. 4730. 4752. 4779. 4788. 4800. 4807. 4811. 4815. 4820. 4825. 4860. 4922 4939 4988 4990 5008 5065 5112 5131 5159 5192 5227 5251 5270 5293 5353 5359 5368 5380 5443 5472 5487 5507 5530 5540 5547 5560 5575 5595 5777 5794 5836 5865 5965 6000 6223 6275 6338 6344 Page 3 6352 5 6375 0 6399 0 6430 0 6440 0 6480 0 6496 0 6537 5 6549 0 6575 5 6607 5 6654 0 6714 5 6753.0 6772.5 6805 0 6820 0 6831 5 6845 5 6870 5 6897 0 6907 5 6956 0 7021 0 7038 0 7053 0 7072 0 7094 0 7103 5 7135 5 7165 5 7183.5 7198.0 7218.0 7223.5 7234.0 7263 0 7276 0 7294 5 7312 0 7341 5 7373 0 7391 0 7403 0 7417 5 7430 0 7449 0 7483 0 7512 0 7527 0 7583 0 7617 5 7711 0 7744 0 7774 0 7963 0 8003 5 8034 0 8166.5 8175.5 8200.5 8222.0 8233.5 8254.0 8275.0 8294.0 8325.5 8341.5 8392.5 8434.5 8457.5 8499.5 8518.0 8569.5 6353.5 6374.5 6399 0 6430 0 6440 0 6480 5 6496 5 6536 5 6548 5 6574 5 6606 0 6654.0 6714.0 6753.0 6772.0 6805.5 6820 0 6831 5 6845 5 6871 0 6898 0 6908 0 6956 5 7023 0 7040 0 7054 0 7073 5 7096 0 7105 5 7137 0 7167 5 7186.0 7201.0 7220.5 7224.5 7235.5 7265.0 7278 0 7294 0 7312 5 7341 5 7372 0 7390 5 7403 0 7417 5 7429 5 7450 0 7479 5 7508 0 7524 0 7581 0 7615 0 7709 0 7742 0 7771 5 7962 0 8002 5 8032 5 8163 5 8173 0 8199.0 8220.5 8231.5 8252.0 8273.0 8292.5 8322.5 8339.5 8390.0 8432.0 8455.5 8496.5 8515.0 8566.5 S-104.tapx Page 4 8601 8611 8654 8675 8700 8712 8721 8741 8749. 8758. 8765. 8785. 8806 8854 8882 8917 8932 8968 8990 9020 9038 9063 9188 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 8599 0 8609 0 8652 0 8673 5 8697 5 8710 5 8718 5 8738 5 8747 0 8754 0 8762 0 8782 5 8802.5 8850.0 8879.0 8913.0 8927.5 8963.0 8985.5 9014.0 9031.5 9058.0 9183.0 S-104.tapx BIT RUN NO MERGE TOP MERGE BASE 1 158.0 1890.0 2 1890.0 3751.0 3 3751.0 8765.0 4 8765.0 9201.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 159.5 9201 ROP MWD FT/H 0 326.66 GR MWD API 11.12 305.76 RPX MWD OHMM 0.42 1825.89 RPS MWD OHMM 0.54 2000 RPM MWD OHMM 0.6 2000 RPD MWD OHMM 0.77 2000 FET MWD HOUR 0.192833 104.978 First Reading For Entire File .......... 159.5 Last Reading For Entire File ........... 9201 First Mean Nsam Reading 4680.25 18084 159.5 109.866 17939 232 81.1145 18058 159.5 6.39588 10960 3701 9.77273 10960 3701 12.5499 10960 3701 18.4432 10960 3701 3.77549 10960 3701 Page 5 Last Reading 9201 9201 9188 9180.5 9180.5 9180.5 9180.5 9180.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 S-104.tapx Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ROP 232.0 9201.0 RPM 8702 5 9180.5 RPD 8702 5 9180.5 RPS 8702 5 9180.5 RPX 8702 5 9180.5 GR 8702 5 9188.0 FET 8702 5 9180.5 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 4 1 232.0 9201.0 $ # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 Page 6 Name Service Unit Min Max DEPT FT 232 9201 ROP MAD FT/H 0 326.66 GR MAD API 36.71 305.76 RPX MAD OHMM 0.86 17.52 RPS MAD OHMM 1 18.96 RPM MAD OHMM 1.08 20.16 RPD MAD OHMM 1.11 21.31 FET MAD HOUR 0.259167 105.289 First Reading For Entire File .......... 232 Last Reading For Entire File ........... 9201 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 S-104.tapx Mean Nsam 4716.5 17939 109.866 17939 109.131 972 4.66923 957 5.06031 957 5.36639 957 5.53699 957 31.0126 957 First Reading 232 232 8702 5 8702 5 8702 5 8702 5 8702 5 8702 5 Last Reading 9201 9201 9188 9180.5 9180.5 9180.5 9180.5 9180.5 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 158.0 1816.5 ROP 230.5 1890.0 $ # LOG HEADER DATA DATE LOGGED: 13-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 1889.0 TOP LOG INTERVAL (FT): 230.0 BOTTOM LOG INTERVAL (FT): 1889.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 38.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02100HWRG6 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 Page 7 S-104.tapx BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 300.0 MUD PH: 8.7 MUD CHLORIDES (PPM): 120 FLUID LOSS (C3): 19.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD0t0 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 61.5 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 158 1890 1024 3465 ROP MWD010 FT/H 0 174.62 67.3296 3320 GR MWD010 API 21.58 111.45 58.3206 3318 First Reading For Entire File .......... 158 Last Reading For Entire File ........... 1890 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 158 230.5 158 Last Reading 1890 1890 1816.5 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 Page 8 S-104.tapx File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1817.0 3684.0 ROP 1890.5 3751.0 $ # LOG HEADER DATA DATE LOGGED: 14-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER {FT): 3751.0 TOP LOG INTERVAL (FT): 1889.0 BOTTOM LOG INTERVAL (FT): 3751.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 41.1 MAXIMUM ANGLE: 57.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02100HWRG6 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT) : # BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 300.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 80 FLUID LOSS (C3): 16.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... .0 73.3 .0 .0 Page 9 S-104.tapx Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 1817 3751 2784 3869 ROP MWD020 FT/H 11.03 326.66 138.984 3722 GR MWD020 API 35.55 133.2 82.9617 3735 First Reading For Entire File .......... 1817 Last Reading For Entire File ........... 3751 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Reading 1817 1890.5 1817 Last Reading 3751 3751 3684 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: START DEPTH 3684.5 3700.0 3700.0 3700.0 3700.0 3700.0 3751.5 STOP DEPTH 8730 0 8722 5 8722 5 8722 5 8722 5 8722 5 8765 0 21-JAN-01 Insite 66.16 Memory 8765.0 3751.0 8765.0 8.1 56.0 Page 10 S-104.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER EWR4 ELECTROMAG. RESIS. 4 PB02100HWRG6 DGR DUAL GAMMA RAY PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.750 3735.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S): 57.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .350 MUD AT MAX CIRCULATING TERMPERATURE: .203 MUD FILTRATE AT MT: .180 MUD CAKE AT MT: .510 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 R?M MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 125.4 70.0 70.0 Name Service Unit Min Max DEPT FT 3684.5 8765 ROP MWD030 FT/H 0 245.08 GR MWD030 API 11.12 300.61 RPX MWD030 OHMM 0.42 1825.89 RPS MWD030 OHMM 0.54 2000 RPM MWD030 OHMM 0.6 2000 RPD MWD030 OHMM 0.77 2000 FET MWD030 HOUR 0.192833 86.414 First Reading For Entire File .......... 3684.5 Last Reading For Entire File ........... 8765 Mean Nsam 6224.75 10162 117.63 10028 86.0326 10092 6.54605 10046 10.2071 10046 13.1979 10046 19.4195 10046 1.643 10046 Page 11 First Reading 3684.5 3751.5 3684.5 3700 3700 3700 3700 3700 Last Reading 8765 8765 8730 8722.5 8722.5 8722.5 8722.5 8722.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 S-104.tapx Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8723.0 9175.5 RPD 8723 0 9175.5 RPM 8723 0 9175.5 RPS 8723 0 9175.5 RPX 8723 0 9175.5 GR 8730 5 9183.0 ROP 8765 5 9196.0 $ # LOG HEADER DATA DATE LOGGED: 27-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9196.0 TOP LOG INTERVAL (FT): 8765.0 BOTTOM LOG INTERVAL (FT): 9196.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 7.7 MAXIMUM ANGLE: 9.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER EWR4 ELECTROMAG. RESIS. 4 PB02100HWRG6 DGR DUAL GAMMA RAY PB02100HWRG6 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3735.0 BOREHOLE CONDITIONS MUD TYPE: 4% KCl CORE MUD DENSITY (LB/G): 10.50 MUD VISCOSITY (S): 86.0 MUD PH: 7.9 MUD CHLORIDES (PPM) : 21000 FLUID LOSS (C3): 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) Page 12 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order S-104.tapx .160 .090 .140 .650 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 65.0 120.2 65.0 65.0 Name Service Unit Min Max DEPT FT 8723 9196 ROP MWD040 FT/H 0.65 156.49 GR MWD040 API 36.71 305.76 RPX MWD040 OHMM 0.86 17.52 RPS MWD040 OHMM 1 18.96 RPM MWD040 OHMM 1.08 20.16 RPD MWD040 OHMM 1.11 21.31 FET MWD040 HOUR 0.259167 104.978 First Reading For Entire File .......... 8723 Last Reading For Entire File ........... 9196 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Mean 8959.5 57.3621 102.227 4.76257 5.15316 5.46932 5.65075 27.1035 Nsam 947 862 906 906 906 906 906 906 First Reading 8723 8765.5 8730.5 8723 8723 8723 8723 8723 Last Reading 9196 9196 9183 9175.5 9175.5 9175.5 9175.5 9175.5 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Page 13 S-104.tapx Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 232.0 9201 0 RPD 8700.0 9175 5 RPM 8700.0 9175 5 RPS 8700.0 9175 5 RPX 8700.0 9175 5 FET 8700.0 9175 5 GR 8700.0 9183 0 $ LOG HEADER DATA DATE LOGGED: 27-JAN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE vERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9196.0 TOP LOG INTERVAL (FT): 8700.0 BOTTOM LOG INTERVAL (FT): 9196.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.7 MAXIMUM ANGLE: 9.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER EWR4 ELECTROMAG. RESIS. 4 PB02100HWRG6 DGR DUAL GAMMA RAY PB02100HWRG6 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3735.0 BOREHOLE CONDITIONS MUD TYPE: 4% KCl CORE MUD DENSITY (LB/G): 10.50 MUD VISCOSITY S): 86.0 MUD PH: 7.9 MUD CHLORIDES PPM): 21000 FLUID LOSS (C3 : 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .160 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .090 120.2 MUD FILTRATE AT MT: .140 65.0 MUD CAKE AT MT: .650 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Page 14 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order S-104.tapx Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MAD041 FT/H 4 1 68 GR MAD041 API 4 1 68 RPX MAD041 OHMM 4 1 68 RPS MAD041 OHMM 4 1 68 RPM MAD041 OHMM 4 1 68 RPD MAD041 OHMM 4 1 68 FET MAD041 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 232 9201 ROP MAD041 FT/H 0 326.66 GR MAD041 API 36.71 305.76 RPX MAD041 OHMM 0.86 17.52 RPS MAD041 OHMM 1 18.96 RPM MAD041 OHMM 1.08 20.16 RPD MAD041 OHMM 1.11 21.31 FET MAD041 HOUR 0.259167 105.289 First Reading For Entire File .......... 232 Last Reading For Entire File ........... 9201 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/02/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 First Last Mean Nsam Reading Reading 4716.5 17939 232 9201 109.866 17939 232 9201 109.02 967 8700 9183 4.65809 952 8700 9175.5 5.04301 952 8700 9175.5 5.34398 952 8700 9175.5 5.51406 952 8700 9175.5 30.8477 952 8700 9175.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/02/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nuraber ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/02/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Page 15 Physical EOF S-104.tapx End Of LIS File Page 16