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Home My WebLink About204-186Nolan 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: 2/8/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type BCU 09A 50133204450100 224113 11/13/2024 YELLOWJACKET GPT-PERF BCU 09A 50133204450100 224113 10/30/2024 YELLOWJACKET GPT BCU 11A 50133205210100 224123 11/9/2024 YELLOWJACKET SCBL BCU 25 50133206440000 214132 11/2/2024 YELLOWJACKET SCBL END 2-74 REVISED 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 HVA 10 50231200280000 204186 11/13/2024 YELLOWJACKET GPT-PERF KU 23-07A 50133207300000 224126 11/23/2024 YELLOWJACKET SCBL NCIU A-21 50883201990000 224086 11/29/2024 AK E-LINE CaliperSurvey PAXTON 6 50133207070000 222054 11/7/2024 YELLOWJACKET PERF PBU 01-37 50029236330000 219073 11/23/2024 BAKER MRPM PBU 06-15A 50029204590200 224108 12/26/2024 BAKER MRPM PBU 06-19B 50029207910200 224095 12/10/2024 BAKER MRPM PBU 07-29E 50029217820500 213001 11/26/2024 BAKER SPN PBU 14-31A 50029209890100 224090 11/10/2024 BAKER MRPM PBU 14-41A 50029222900100 224076 11/9/2024 BAKER MRPM SRU 241-33B 50133206960000 221053 11/5/2024 YELLOWJACKET GPT-PERF Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. T40053 T40053 T40054 T40055 T40056 T40057 T40058 T40059 T40060 T40061 T40062 T40063 T40064 T40065 T40066 T40067 HVA 10 50231200280000 204186 11/13/2024 YELLOWJACKET GPT-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.07 13:25:23 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,420 feet N/A feet true vertical 6,930 feet 8,102 feet Effective Depth measured 8,348 feet 3,616 feet true vertical 6,861 feet 2,836 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,660' MD 2,866' TVD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr; N/A 3,616' MD 2,836' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Scott Warner, Operations Engineer 324-605 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 83 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 73' 5 0200 0 690 75 7" 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-186 50-231-20028-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE CIRI Deep Creek - HV Beluga/Tyonek Gas Happy Valley (HV) A-10 Plugs Junk measured Length measured true vertical Production Liner 3,850' 4,800' Casing Structural 2,995' 6,926' 3,850' 8,416' 73'Conductor Surface Intermediate 13-3/8" 9-5/8" 73' 941' TVD 5,410psi 10,540psi 5,380psi 5,750psi 7,240psi 10,160psi 941' 924' Burst Collapse 2,670psi 3,090psi measured Packer p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Chad Helgeson for Noel Nocas Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517) Date: 2024.12.13 09:11:37 - 09'00' Chad Helgeson (1517) By Grace Christianson at 9:36 am, Dec 13, 2024 Page 1/1 Well Name: DCU HVA-010 Report Printed: 12/10/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:11/12/2024 End Date: Report Number 1 Report Start Date 11/13/2024 Report End Date 11/14/2024 Last 24hr Summary PTW/PJSM. MIRU Yellow Jacket E-line. P-test 250/2500 psi. Perf the BEL 47 from 5,308' - 5,314' with well shut-in. SDFN. Prod Ops flow testing well. Report Number 2 Report Start Date 11/14/2024 Report End Date 11/15/2024 Last 24hr Summary PTW/PJSM. Perf the BEL 45 from 5,205' - 5,214' with well shut-in. Flow test well. Perf the BEL 41 from 4,942' - 4,948' with well shut-in. SDFN. Prod Ops flowing well. Report Number 3 Report Start Date 11/15/2024 Report End Date 11/16/2024 Last 24hr Summary PTW/PJSM. Perf the BEL 37 from 4,527'- 4,547' with well shut-in. Flow test well. Run flowing GPT survey. RDMO E-line. Field: Deep Creek Unit Sundry #: 324-605 State: ALASKA Rig/Service:Permit to Drill (PTD) #:204-186Permit to Drill (PTD) #:204-186 Wellbore API/UWI:50-231-20028-00-00 _____________________________________________________________________________________ Updated by DMA 12-10-24 SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 PTD: 204-186 API # 50-231-20028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8'Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8"Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7"Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850 3-1/2"Liner 9.2 / L-80 / IBT-Mod 2.992 3,6168,416' TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,660 NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth ID Item 1 2,5022.8671 Sidepocket Chemical Injection Mandrel / Macco SFO-CI (WFD) 2 3,6164.00Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,6603.00Locator Sub and 80-40 Seal Sub PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Gun Size Date Status BEL 37 4,527'4,547'3,505'3,520'20 2-3/811/15/24 Open BEL 41 4,942'4,948'3,842'3,847'6 2-3/811/14/24 Open BEL 45 5,205'5,214'4,058'4,066'9 2-3/811/14/24 Open BEL 47 5,308'5,314'4,141'4,148'6 2-3/811/13/24 Open BEL 50-51 5,4145,4214,2324,2387 212/18/20 Open 5,4145,4224,2324,2398 2-3/84/16/21 Open 5,4175,4194,2354,2372 212/17/20 Open 5,4305,4364,2464,2516 212/18/20 Open 5,4305,437 4,2464,2527 2-3.84/16/21 Open 5,4325,4344,2484,2492 212/17/20 Open 5,4565,4664,2684,27610 212/18/20 Open 5,4605,4624,2714,2732 212/17/20 Open 5,478 5,498 4,286 4,30320 212/17/20 Open 5,478 5,498 4,286 4,30320 2-3/84/8/21 Open 5,487 5,489 4,294 4,2952 212/17/20 Open BEL_55 5,606 5,615 4,293 4,4019 04/19/22 Open BEL_70 5,824 5,835 4,578 4,58711 04/19/22 Open BEL_78 5,985 5,993 4,715 4,7218 04/19/22 Open BEL_92 6,327 6,339 5,009 5,01912 04/19/22 Open BEL_93 6,355 6,369 5,033 5,04614 04/18/22 Open BEL_132 6,992 6,999 5,597 5,6047 04/18/22 Open T-1 7,236 7,253 5,819 5,83517 2-3/81/18/20 Open T-2B 7,334 7,341 5,909 5,9167 2-3/81/17/20 Open T-3u 7,354 7,360 5,928 5,9336 04/18/22 Open T-3l 7,365 7,382 5,938 5,95317 04/18/22 Open T-6u 7,438 7,442 6,006 6,0094 04/18/22 Open T-6l 7,457 7,461 6,023 6,0264 04/18/22 Open T-6 7,481 7,506 6,045 6,06825 2-3/812/15/15 Open T-6 7,517 7,520 6,078 6,0813 2-3/84/16/21 Open T-6A 7,546 7,571 6,105 6,12825 2-3/812/15/15 Open T-7u 7,660 7,667 6,211 6,2177 04/18/22 Open 7,696 7,701 6,245 6,2505 2-3/84/16/21 Open T-10 7,830 7,885 6,371 6,39455 212/11/05 Open 7,844 7,854 6,384 6,39310 2-1/211/19/04 Open 7,844 7,854 6,384 6,39310 25/5/05 Open 7,860 7,880 6,399 6,417 20 2-3/84/16/21 Open T-17 8,198 8,228 6,718 6,74730 25/4/05 Open 8,198 8,246 6,718 6,74748 2-1/211/10&19/04 Open 8,218 8,246 6,737 6,76428 2-1/25/2/05 Open 9-5/8 cement job:12-1/4 hole. 46bbls of 12.8# class G lead, and 31bbls of 15.8# class G tail. 20bbls cement mix back to surface 7 cement job:8-1/2 hole. 75bbls of 12.8# lead, and 14bbls of 15.8# class G tail. No losses noted. Volumetric ToC with 10% OH washout assumed = 350 MD 3-1/2 cement job:6-1/8 hole. 155bbls of 12.0# Litecrete. ToC at 4460 MD from 11/1/04 SCMT. FISH at 8102 MD: 2-3/8 spent perf gun with overshot and bait sub planted on top (OAL: 41) 4/10/21 Fish recovered on 7/1/21 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,420'8,102' Casing Collapse Structural Conductor 2,670psi Surface 3,090psi Intermediate 5,410psi Production 10,540psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writte n approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE-CIRI 204-186 50-231-20028-00-00 Hilcorp Alaska, LLC Proposed Pools: 9.2 / L-80 TVD Burst 3,660' 10,160psi 924' Size 73' 7"3,850' 941' MD See Attached Schematic 7,240psi 5,380psi 5,750psi 73' 2,995' 73' 941' October 25, 2024 3-1/2" 8,416' Perforation Depth MD (ft): 3,850' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Happy Valley (HV) A-10CO 553A.001 Same 6,926'3-1/2" ~2,223 4,800' N/A Length Baker ZXP Packer & N/A 3,616 (MD) 2,836 (TVD) & N/A 6,930'8,348'6,861' Deep Creek HV Beluga/Tyonek Gas 13-3/8" 9-5/8" See Attached Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:38 am, Oct 21, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.10.17 16:22:06 - 08'00' Noel Nocas (4361) 324-605 SFD 10/26/2024BJM 10/29/24 10-404 DSR-10/23/24JLC 10/29/2024 Gregory Wilson Digitally signed by Gregory Wilson Date: 2024.10.30 05:12:19 -08'00'10/30/24 RBDMS JSB 103024 Well Prognosis Well: HVA-10 Well Name: HVA-10 API Number: 50-231-20028-00-00 Current Status: Producing Gas Well Permit to Drill Number: 204-186 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 2897 psi @ 6737’ TVD Based on 0.43 psi/ft Max. Potential Surface Pressure:2223 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.72 psi/ft using 13.8 ppg EMW FIT at the 9-5/8” int. casing shoe Shallowest Allowable Perf TVD: N/A- Proposed perforations are above existing perfs Top of Applicable Gas Pool: 2806’ MD/ 2285’ TVD (Tyonek/Beluga) Well Status: Online Gas producer flowing at 105 mscfd, 2 bwpd, 69 psi FTP Brief Well Summary Happy Valley A-10 was drilled and completed in November 2004 using a water-based mud product. Initially the Tyonek 17 and 10 sands were shot – resulting in production rates of 1.2 MMCFD while slowly increasing. In response to the increasing gas rates, the same sand intervals were reperforated – these paid dividends when rates responded and increased to 4.7 MMCFD, suggesting that formation damage or perforation damage might have been at play. In December 2005, additional T10 sands were shot – a slight increase in rate of 0.6 MMCFD was observed. The well continued to decline, in December 2015, the T6 and T6A sands were perforated – this resulted in a gas rate increase of 0.6 MMCFD. Decline continued gradually and a series of perforation events were executed. In January 2020 the T1 & T2 sands were shot – an instantaneous jump of 0.3 MMCFD was observed but did not last. In December 2020, the BEL_50 and BEL_51 sands were shot with no response noted on the production trend, however, when a PT survey was logged post perf cooling was observed at the BEL-50 suggesting slight contribution from the sand. In April 2021, the BEL50 and BEL_51 sands were reshot and the T6, T7, & T10 sands were also added – no response was observed and shortly after perforating the rate dropped by 150 MCFD to 130 MCFD. April 2022, T-7, T-6, T-3, Bel 132, Bel 93, Bel 92, Bel 78, Bel 70 and Bel 55 sands were perforated which increased rate from 30 mcfd to 200 mcfd. The purpose of this sundry is to add additional perforations in the Bel 37, 41, 45, and 47 sands to increase rate. Notes Regarding Wellbore Condition x Inclination o Max inclination = 49° at 1920’ MD o Max DLS: 5.09° at 1037’ MD x Recent Tags o 8/7/24: SL RIH w/ 2.80” GR and tag at 8126’ KB. Feel slow past 8000’. Ran PT survey o 4/20/22: EL perforated multiple Tyonek and Beluga sands with 2-3/8” guns. Fluid level seen at 3380’ Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /2,500 psi high 3. RIH and perforate Bel 37, 41, 45, and 47 sands from bottom up with 2-3/8” 60 deg phased perf guns: See attached email from Scott Warner explaining that existing perfs are depleted thus allowing all proposed perfs to be open without risk of frac'ing out of zone. -bjm Proposed perforations are above existing perfs ? SFD Well Prognosis Well: HVA-10 Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval BEL 37 ±4,524'±4,549'±3,502'±3,522'±25' BEL 41 ±4,942' ±4,949' ±3,842' ±3,848' ±7' BEL 45 ±5,205' ±5,214' ±4,058' ±4,066' ±9' BEL 47 ±5,307' ±5,314' ±4,142' ±4,148' ±7' x Recent SITP pressures have not exceeded 500 psi proving existing perfs have been depleted and are not at original pressure. a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Recent SITP pressures have not exceeded 500 psi proving existing perfs have been depleted and are not at original pressure. The original Daily Drilling Operations Report of 10/5/2004 states: "Perform LOT 13.8 ppg EMW." (See Well History File 204-186, p. 73.) With a LOT of 13.8 ppg and the reported well configuration, the shallowest allowable perforation depth is about 4,650' MD / 3,605 TVD. SFD See attached email from Scott Warner explaining that existing perfs are depleted thus allowing all proposed perfs to be open without risk of frac'ing out of zone. -bjm _____________________________________________________________________________________ Updated by SRW 8/6/24 SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 PTD: 204-186 API # 50-231-20028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8'Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8"Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7"Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”"Liner 9.2 / L-80 / IBT-Mod 2.992 3,616’8,416' TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,660’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth ID Item 1 2,502’2.867”1” Sidepocket Chemical Injection Mandrel / Macco SFO-CI (WFD) 2 3,616’4.00”Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,660’3.00”Locator Sub and 80-40 Seal Sub PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD) Btm (TVD)FT Gun Size Date Status BEL 50-51 5,414’5,421’4,232’4,238’7 2”12/18/20 Open 5,414’5,422’4,232’4,239’8 2-3/8”4/16/21 Open 5,417’5,419’4,235’4,237’2 2”12/17/20 Open 5,430’5,436’4,246’4,251’6 2”12/18/20 Open 5,430’5,437 4,246’4,252’7 2-3.8”4/16/21 Open 5,432’5,434’4,248’4,249’2 2”12/17/20 Open 5,456’5,466’4,268’4,276’10 2”12/18/20 Open 5,460’5,462’4,271’4,273’2 2”12/17/20 Open 5,478’5,498’4,286’4,303’20 2”12/17/20 Open 5,478’5,498’4,286’4,303’20 2-3/8”4/8/21 Open 5,487’5,489’4,294’4,295’2 2”12/17/20 Open BEL_55 5,606’5,615’4,293’4,401’9 04/19/22 Open BEL_70 5,824’5,835’4,578’4,587’11 04/19/22 Open BEL_78 5,985’5,993’4,715’4,721’8 04/19/22 Open BEL_92 6,327’6,339’5,009’5,019’12 04/19/22 Open BEL_93 6,355’6,369’5,033’5,046’14 04/18/22 Open BEL_132 6,992’6,999’5,597’5,604’7 04/18/22 Open T-1 7,236’7,253’5,819’5,835’17 2-3/8”1/18/20 Open T-2B 7,334’7,341’5,909’5,916’7 2-3/8”1/17/20 Open T-3u 7,354’7,360’5,928’5,933’6 04/18/22 Open T-3l 7,365’7,382’5,938’5,953’17 04/18/22 Open T-6u 7,438’7,442’6,006’6,009’4 04/18/22 Open T-6l 7,457’7,461’6,023’6,026’4 04/18/22 Open T-6 7,481’7,506’6,045’6,068’25 2-3/8”12/15/15 Open T-6 7,517’7,520’6,078’6,081’3 2-3/8”4/16/21 Open T-6A 7,546’7,571’6,105’6,128’25 2-3/8”12/15/15 Open T-7u 7,660’7,667’6,211’6,217’7 04/18/22 Open 7,696’7,701’6,245’6,250’5 2-3/8”4/16/21 Open T-10 7,830’7,885’6,371’6,394’55 2”12/11/05 Open 7,844’7,854’6,384’6,393’10 2-1/2”11/19/04 Open 7,844’7,854’6,384’6,393’10 2”5/5/05 Open 7,860’7,880’6,399’6,417’20’2-3/8”4/16/21 Open T-17 8,198’8,228’6,718’6,747’30 2”5/4/05 Open 8,198’8,246’6,718’6,747’48 2-1/2”11/10&19/04 Open 8,218 8,246’6,737’6,764’28 2-1/2”5/2/05 Open 9-5/8” cement job:12-1/4” hole. 46bbls of 12.8# class G lead, and 31bbls of 15.8# class G tail. 20bbls cement mix back to surface 7” cement job:8-1/2” hole. 75bbls of 12.8# lead, and 14bbls of 15.8# class G tail. No losses noted. Volumetric ToC with 10% OH washout assumed = 350’ MD 3-1/2” cement job:6-1/8” hole. 155bbls of 12.0# Litecrete. ToC at 4460’ MD from 11/1/04 SCMT. FISH at 8102’ MD: 2-3/8” spent perf gun with overshot and bait sub planted on top (OAL: 41’) 4/10/21 x Fish recovered on 7/1/21 _____________________________________________________________________________________ Updated by SRW 10/8/24 PROPOSED Deep Creek (Happy Valley) Well: HVA-10 PTD: 204-186 API # 50-231-20028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8'Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8"Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7"Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”"Liner 9.2 / L-80 / IBT-Mod 2.992 3,616’8,416' TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,660’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth ID Item 1 2,502’2.867”1” Sidepocket Chemical Injection Mandrel / Macco SFO-CI (WFD) 2 3,616’4.00”Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,660’3.00”Locator Sub and 80-40 Seal Sub PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD) Btm (TVD)FT Gun Size Date Status BEL 37 ±4,524'±4,549'±3,502'±3,522'±25'2-3/8”TBD Proposed BEL 41 ±4,942'±4,949'±3,842'±3,848'±7'2-3/8”TBD Proposed BEL 45 ±5,205'±5,214'±4,058'±4,066'±9'2-3/8”TBD Proposed BEL 47 ±5,307'±5,314'±4,142'±4,148'±7'2-3/8”TBD Proposed BEL 50-51 5,414’5,421’4,232’4,238’7 2”12/18/20 Open 5,414’5,422’4,232’4,239’8 2-3/8”4/16/21 Open 5,417’5,419’4,235’4,237’2 2”12/17/20 Open 5,430’5,436’4,246’4,251’6 2”12/18/20 Open 5,430’5,437 4,246’4,252’7 2-3.8”4/16/21 Open 5,432’5,434’4,248’4,249’2 2”12/17/20 Open 5,456’5,466’4,268’4,276’10 2”12/18/20 Open 5,460’5,462’4,271’4,273’2 2”12/17/20 Open 5,478’5,498’4,286’4,303’20 2”12/17/20 Open 5,478’5,498’4,286’4,303’20 2-3/8”4/8/21 Open 5,487’5,489’4,294’4,295’2 2”12/17/20 Open BEL_55 5,606’5,615’4,293’4,401’9 04/19/22 Open BEL_70 5,824’5,835’4,578’4,587’11 04/19/22 Open BEL_78 5,985’5,993’4,715’4,721’8 04/19/22 Open BEL_92 6,327’6,339’5,009’5,019’12 04/19/22 Open BEL_93 6,355’6,369’5,033’5,046’14 04/18/22 Open BEL_132 6,992’6,999’5,597’5,604’7 04/18/22 Open T-1 7,236’7,253’5,819’5,835’17 2-3/8”1/18/20 Open T-2B 7,334’7,341’5,909’5,916’7 2-3/8”1/17/20 Open T-3u 7,354’7,360’5,928’5,933’6 04/18/22 Open T-3l 7,365’7,382’5,938’5,953’17 04/18/22 Open T-6u 7,438’7,442’6,006’6,009’4 04/18/22 Open T-6l 7,457’7,461’6,023’6,026’4 04/18/22 Open T-6 7,481’7,506’6,045’6,068’25 2-3/8”12/15/15 Open T-6 7,517’7,520’6,078’6,081’3 2-3/8”4/16/21 Open T-6A 7,546’7,571’6,105’6,128’25 2-3/8”12/15/15 Open T-7u 7,660’7,667’6,211’6,217’7 04/18/22 Open 7,696’7,701’6,245’6,250’5 2-3/8”4/16/21 Open T-10 7,830’7,885’6,371’6,394’55 2”12/11/05 Open 7,844’7,854’6,384’6,393’10 2-1/2”11/19/04 Open 7,844’7,854’6,384’6,393’10 2”5/5/05 Open 7,860’7,880’6,399’6,417’20’2-3/8”4/16/21 Open T-17 8,198’8,228’6,718’6,747’30 2”5/4/05 Open 8,198’8,246’6,718’6,747’48 2-1/2”11/10&19/04 Open 8,218 8,246’6,737’6,764’28 2-1/2”5/2/05 Open 9-5/8” cement job:12-1/4” hole. 46bbls of 12.8# class G lead, and 31bbls of 15.8# class G tail. 20bbls cement mix back to surface 7” cement job:8-1/2” hole. 75bbls of 12.8# lead, and 14bbls of 15.8# class G tail. No losses noted. Volumetric ToC with 10% OH washout assumed = 350’ MD 3-1/2” cement job:6-1/8” hole. 155bbls of 12.0# Litecrete. ToC at 4460’ MD from 11/1/04 SCMT. FISH at 8102’ MD: 2-3/8” spent perf gun with overshot and bait sub planted on top (OAL: 41’) 4/10/21 x Fish recovered on 7/1/21 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1 McLellan, Bryan J (OGC) From:Scott Warner <scott.warner@hilcorp.com> Sent:Tuesday, October 29, 2024 12:48 PM To:Davies, Stephen F (OGC) Cc:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] HV A-10 (Permit 204-186, Sundry 324-605) - Question Steve, I didn’t provide the calculation because the highest potential pressure in this reservoir will only be the zones we have proposed to be perforated. We have recent shut in tubing pressures that have maxed out at ~500 psi therefore I should’ve put that as the current maximum potential surface pressure instead of the 2223 psi that I put in the sundry which is based off original pressures and is no longer true since the open zones are much lower pressure now but still producing ~100 mscfd. Using the newest proposed perforation TVD depths starting at 4142’ TVD, the shallowest allowable perf calculation comes out to be: x Max expected BHP: 1781 psi @ 4142’ TVD x Max potential surface pressure: 1367 psi x Applicable frac gradient: .72 psi/ft using 13.8 ppg EMW FIT at the 9-5/8” int. casing shoe x Shallowest allowable perf TVD: MPSP/(.72-.1) = 1367/ (.62) = 2204’ TVD Thanks, ScoƩ Warner Kenai – OperaƟons Engineer Oĸce: (907) 564-4506 Cell: (907) 830-8863 To help protect your priv acy, Microsoft Office prevented automatic download of this picture from the Internet. From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Wednesday, October 23, 2024 9:46 AM To: Scott Warner <scott.warner@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] HV A-10 (Permit 204-186, Sundry 324-605) - Question Scott, 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. 2 I’m reviewing Hilcorp’s Sundry Application to perforate HV A-10. The application states: Could you please provide the shallowest allowable perforation calculation for this well to ensure that Hilcorp’s planned perforations between 4524’ and 4549’ MD within the Beluga 37 well are allowable? Thanks and Be Well, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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>ͺϵϮ ϲ͕ϯϮϳ͛ ϲ͕ϯϯϵ͛ ϱ͕ϬϬϵ͛ ϱ͕Ϭϭϵ͛ ϭϮ ϬϰͬϭϵͬϮϮ KƉĞŶ >ͺϵϯ ϲ͕ϯϱϱ͛ ϲ͕ϯϲϵ͛ ϱ͕Ϭϯϯ͛ ϱ͕Ϭϰϲ͛ ϭϰ ϬϰͬϭϴͬϮϮ KƉĞŶ >ͺϭϯϮ ϲ͕ϵϵϮ͛ ϲ͕ϵϵϵ͛ ϱ͕ϱϵϳ͛ ϱ͕ϲϬϰ͛ ϳ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϭ ϳ͕Ϯϯϲ͛ ϳ͕Ϯϱϯ͛ ϱ͕ϴϭϵ͛ ϱ͕ϴϯϱ͛ ϭϳ ϮͲϯͬϴ͟ ϭͬϭϴͬϮϬ KƉĞŶ dͲϮ ϳ͕ϯϯϰ͛ ϳ͕ϯϰϭ͛ ϱ͕ϵϬϵ͛ ϱ͕ϵϭϲ͛ ϳ ϮͲϯͬϴ͟ ϭͬϭϳͬϮϬ KƉĞŶ dͲϯƵ ϳ͕ϯϱϰ͛ ϳ͕ϯϲϬ͛ ϱ͕ϵϮϴ͛ ϱ͕ϵϯϯ͛ ϲ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϯů ϳ͕ϯϲϱ͛ ϳ͕ϯϴϮ͛ ϱ͕ϵϯϴ͛ ϱ͕ϵϱϯ͛ ϭϳ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϲƵ ϳ͕ϰϯϴ͛ ϳ͕ϰϰϮ͛ ϲ͕ϬϬϲ͛ ϲ͕ϬϬϵ͛ ϰ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϲů ϳ͕ϰϱϳ͛ ϳ͕ϰϲϭ͛ ϲ͕ϬϮϯ͛ ϲ͕ϬϮϲ͛ ϰ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϲ ϳ͕ϰϴϭ͛ ϳ͕ϱϬϲ͛ ϲ͕Ϭϰϱ͛ ϲ͕Ϭϲϴ͛ Ϯϱ ϮͲϯͬϴ͟ ϭϮͬϭϱͬϭϱ KƉĞŶ dͲϲ ϳ͕ϱϭϳ͛ ϳ͕ϱϮϬ͛ ϲ͕Ϭϳϴ͛ ϲ͕Ϭϴϭ͛ ϯ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϳ ϳ͕ϱϰϲ͛ ϳ͕ϱϳϭ͛ ϲ͕ϭϬϱ͛ ϲ͕ϭϮϴ͛ Ϯϱ ϮͲϯͬϴ͟ ϭϮͬϭϱͬϭϱ KƉĞŶ dͲϳƵ ϳ͕ϲϲϬ͛ ϳ͕ϲϲϳ͛ ϲ͕Ϯϭϭ͛ ϲ͕Ϯϭϳ͛ ϳ ϬϰͬϭϴͬϮϮ KƉĞŶ ϳ͕ϲϵϲ͛ ϳ͕ϳϬϭ͛ ϲ͕Ϯϰϱ͛ ϲ͕ϮϱϬ͛ ϱ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϬ ϳ͕ϴϯϬ͛ ϳ͕ϴϴϱ͛ ϲ͕ϯϳϭ͛ ϲ͕ϯϵϰ͛ ϱϱ Ϯ͟ ϭϮͬϭϭͬϬϱ KƉĞŶ ϳ͕ϴϰϰ͛ ϳ͕ϴϱϰ͛ ϲ͕ϯϴϰ͛ ϲ͕ϯϵϯ͛ ϭϬ ϮͲϭͬϮ͟ ϭϭͬϭϵͬϬϰ KƉĞŶ ϳ͕ϴϰϰ͛ ϳ͕ϴϱϰ͛ ϲ͕ϯϴϰ͛ ϲ͕ϯϵϯ͛ ϭϬ Ϯ͟ ϱͬϱͬϬϱ KƉĞŶ ϳ͕ϴϲϬ͛ ϳ͕ϴϴϬ͛ ϲ͕ϯϵϵ͛ ϲ͕ϰϭϳ͛ ϮϬ͛ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϳ ϴ͕ϭϵϴ͛ ϴ͕ϮϮϴ͛ ϲ͕ϳϭϴ͛ ϲ͕ϳϰϳ͛ ϯϬ Ϯ͟ ϱͬϰͬϬϱ KƉĞŶ ϴ͕ϭϵϴ͛ ϴ͕Ϯϰϲ͛ ϲ͕ϳϭϴ͛ ϲ͕ϳϰϳ͛ ϰϴ ϮͲϭͬϮ͟ ϭϭͬϭϬΘϭϵͬϬϰ KƉĞŶ ϴ͕Ϯϭϴ ϴ͕Ϯϰϲ͛ ϲ͕ϳϯϳ͛ ϲ͕ϳϲϰ͛ Ϯϴ ϮͲϭͬϮ͟ ϱͬϮͬϬϱ KƉĞŶ ϵͲϱͬϴ͟ĐĞŵĞŶƚũŽď͗ϭϮͲϭͬϰ͟ŚŽůĞ͘ϰϲďďůƐŽĨϭϮ͘ϴηĐůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϭďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘ϮϬďďůƐĐĞŵĞŶƚ ŵŝǆďĂĐŬƚŽƐƵƌĨĂĐĞ ϳ͟ĐĞŵĞŶƚũŽď͗ϴͲϭͬϮ͟ŚŽůĞ͘ϳϱďďůƐŽĨϭϮ͘ϴηůĞĂĚ͕ĂŶĚϭϰďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘EŽůŽƐƐĞƐŶŽƚĞĚ͘sŽůƵŵĞƚƌŝĐ dŽǁŝƚŚϭϬйK,ǁĂƐŚŽƵƚĂƐƐƵŵĞĚсϯϱϬ͛D ϯͲϭͬϮ͟ĐĞŵĞŶƚũŽď͗ϲͲϭͬϴ͟ŚŽůĞ͘ϭϱϱďďůƐŽĨϭϮ͘Ϭη>ŝƚĞĐƌĞƚĞ͘dŽĂƚϰϰϲϬ͛DĨƌŽŵϭϭͬϭͬϬϰ^Dd͘ &/^,ĂƚϴϭϬϮ͛D͗ϮͲϯͬϴ͟ƐƉĞŶƚƉĞƌĨŐƵŶǁŝƚŚŽǀĞƌƐŚŽƚĂŶĚďĂŝƚƐƵďƉůĂŶƚĞĚŽŶƚŽƉ;K>͗ϰϭ͛ͿϰͬϭϬͬϮϭ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ:>>ϬϴͬϮϮͬϮϮ WZKWK^ ĞĞƉƌĞĞŬ;,ĂƉƉǇsĂůůĞǇͿ tĞůů͗,sͲϭϬ Wd͗ϮϬϰͲϭϴϲ W/ηϱϬͲϮϯϭͲϮϬϬϮϴͲϬϬͲϬϬ dсϴ͕ϰϮϬ͛;DͿͬϲ͕ϵϯϬ͛;dsͿ Z<͗D^>сϭϲ͘ϰ͛ ϳ͟ Ϯ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ ϭ dͲϭϬ ϯͲϭͬϮ͟ Wdсϴ͕ϯϰϴ͛;DͿͬϲ͕ϴϲϭ͛;dsͿ dͲϭϳ ϯ dͲϳ dͲϲ dͲϮ dͲϭ %(/ dKΛϰ͕ϰϲϬ͛ ;ϭϭͬϭͬϬϰ^DdͿ %(/ %(/ %(/ %(/ %(/ %(/ dͲ ϯ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΖ ŽŶĚƵĐƚŽƌ ϳϮͬEͲϴϬͬdͲDŽĚ ϭϮ͘ϯϰϳ ^ƵƌĨ ϳϯΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdͲDŽĚ ϴ͘ϴϯϱ ^ƵƌĨ ϵϰϭ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲDŽĚ ϲ͘Ϯϳϲ ^ƵƌĨ ϯ͕ϴϱϬ͛ ϯͲϭͬϮ͟Η >ŝŶĞƌ ϵ͘Ϯͬ>ͲϴϬͬ/dͲDŽĚ Ϯ͘ϵϵϮ ϯ͕ϲϭϲ͛ ϴ͕ϰϭϲΖ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬ/dͲDŽĚ Ϯ͘ϵϵϮ ^ƵƌĨ ϯ͕ϲϲϬ͛ ϯͬϴ͟ ĂƉŝůůĂƌǇ^ƚƌŝŶŐ ^ƵƌĨ цϴ͕ϬϬϬ͛ EKd͗ŶŶƵůƵƐ>ŽĂĚĞĚǁŝƚŚϯй<ůƌŝŶĞWůƵƐŽƌƌŽƐŝŽŶ/ŶŚŝďŝƚŽƌ :t>Zzd/> EŽ ĞƉƚŚ / /ƚĞŵ ϭ Ϯ͕ϱϬϮ͛ Ϯ͘ϴϲϳ͟ ϭ͟^ŝĚĞƉŽĐŬĞƚŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶDĂŶĚƌĞůͬDĂĐĐŽ^&KͲ/;t&Ϳ Ϯ ϯ͕ϲϭϲ͛ ϰ͘ϬϬ͟ ĂŬĞƌyWWĂĐŬĞƌ͕&ůĞǆůŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌΘϴϬͲϰϬ^ĞĂůďŽƌĞ ϯ ϯ͕ϲϲϬ͛ ϯ͘ϬϬ͟ >ŽĐĂƚŽƌ^ƵďĂŶĚϴϬͲϰϬ^ĞĂů^Ƶď WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d 'ƵŶ ^ŝǌĞ ĂƚĞ ^ƚĂƚƵƐ >ϱϬͲϱϭ ϱ͕ϰϭϰ͛ ϱ͕ϰϮϭ͛ ϰ͕ϮϯϮ͛ ϰ͕Ϯϯϴ͛ ϳ Ϯ͟ ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϭϰ͛ ϱ͕ϰϮϮ͛ ϰ͕ϮϯϮ͛ ϰ͕Ϯϯϵ͛ ϴ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ ϱ͕ϰϭϳ͛ ϱ͕ϰϭϵ͛ ϰ͕Ϯϯϱ͛ ϰ͕Ϯϯϳ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϯϬ͛ ϱ͕ϰϯϲ͛ ϰ͕Ϯϰϲ͛ ϰ͕Ϯϱϭ͛ ϲ Ϯ͟ ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϯϬ͛ ϱ͕ϰϯϳ ϰ͕Ϯϰϲ͛ ϰ͕ϮϱϮ͛ ϳ ϮͲϯ͘ϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ ϱ͕ϰϯϮ͛ ϱ͕ϰϯϰ͛ ϰ͕Ϯϰϴ͛ ϰ͕Ϯϰϵ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϱϲ͛ ϱ͕ϰϲϲ͛ ϰ͕Ϯϲϴ͛ ϰ͕Ϯϳϲ͛ ϭϬ Ϯ͟ ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϲϬ͛ ϱ͕ϰϲϮ͛ ϰ͕Ϯϳϭ͛ ϰ͕Ϯϳϯ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϳϴ͛ ϱ͕ϰϵϴ͛ ϰ͕Ϯϴϲ͛ ϰ͕ϯϬϯ͛ ϮϬ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϳϴ͛ ϱ͕ϰϵϴ͛ ϰ͕Ϯϴϲ͛ ϰ͕ϯϬϯ͛ ϮϬ ϮͲϯͬϴ͟ ϰͬϴͬϮϭ KƉĞŶ ϱ͕ϰϴϳ͛ ϱ͕ϰϴϵ͛ ϰ͕Ϯϵϰ͛ ϰ͕Ϯϵϱ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ >ͺϱϱ ϱ͕ϲϬϲ͛ ϱ͕ϲϭϱ͛ ϰ͕Ϯϵϯ͛ ϰ͕ϰϬϭ͛ ϵ ϬϰͬϭϵͬϮϮ KƉĞŶ >ͺϳϬ ϱ͕ϴϮϰ͛ ϱ͕ϴϯϱ͛ ϰ͕ϱϳϴ͛ ϰ͕ϱϴϳ͛ ϭϭ ϬϰͬϭϵͬϮϮ KƉĞŶ >ͺϳϴ ϱ͕ϵϴϱ͛ ϱ͕ϵϵϯ͛ ϰ͕ϳϭϱ͛ ϰ͕ϳϮϭ͛ ϴ ϬϰͬϭϵͬϮϮ KƉĞŶ >ͺϵϮ ϲ͕ϯϮϳ͛ ϲ͕ϯϯϵ͛ ϱ͕ϬϬϵ͛ ϱ͕Ϭϭϵ͛ ϭϮ ϬϰͬϭϵͬϮϮ KƉĞŶ >ͺϵϯ ϲ͕ϯϱϱ͛ ϲ͕ϯϲϵ͛ ϱ͕Ϭϯϯ͛ ϱ͕Ϭϰϲ͛ ϭϰ ϬϰͬϭϴͬϮϮ KƉĞŶ >ͺϭϯϮ ϲ͕ϵϵϮ͛ ϲ͕ϵϵϵ͛ ϱ͕ϱϵϳ͛ ϱ͕ϲϬϰ͛ ϳ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϭ ϳ͕Ϯϯϲ͛ ϳ͕Ϯϱϯ͛ ϱ͕ϴϭϵ͛ ϱ͕ϴϯϱ͛ ϭϳ ϮͲϯͬϴ͟ ϭͬϭϴͬϮϬ KƉĞŶ dͲϮ ϳ͕ϯϯϰ͛ ϳ͕ϯϰϭ͛ ϱ͕ϵϬϵ͛ ϱ͕ϵϭϲ͛ ϳ ϮͲϯͬϴ͟ ϭͬϭϳͬϮϬ KƉĞŶ dͲϯƵ ϳ͕ϯϱϰ͛ ϳ͕ϯϲϬ͛ ϱ͕ϵϮϴ͛ ϱ͕ϵϯϯ͛ ϲ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϯů ϳ͕ϯϲϱ͛ ϳ͕ϯϴϮ͛ ϱ͕ϵϯϴ͛ ϱ͕ϵϱϯ͛ ϭϳ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϲƵ ϳ͕ϰϯϴ͛ ϳ͕ϰϰϮ͛ ϲ͕ϬϬϲ͛ ϲ͕ϬϬϵ͛ ϰ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϲů ϳ͕ϰϱϳ͛ ϳ͕ϰϲϭ͛ ϲ͕ϬϮϯ͛ ϲ͕ϬϮϲ͛ ϰ ϬϰͬϭϴͬϮϮ KƉĞŶ dͲϲ ϳ͕ϰϴϭ͛ ϳ͕ϱϬϲ͛ ϲ͕Ϭϰϱ͛ ϲ͕Ϭϲϴ͛ Ϯϱ ϮͲϯͬϴ͟ ϭϮͬϭϱͬϭϱ KƉĞŶ dͲϲ ϳ͕ϱϭϳ͛ ϳ͕ϱϮϬ͛ ϲ͕Ϭϳϴ͛ ϲ͕Ϭϴϭ͛ ϯ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϳ ϳ͕ϱϰϲ͛ ϳ͕ϱϳϭ͛ ϲ͕ϭϬϱ͛ ϲ͕ϭϮϴ͛ Ϯϱ ϮͲϯͬϴ͟ ϭϮͬϭϱͬϭϱ KƉĞŶ dͲϳƵ ϳ͕ϲϲϬ͛ ϳ͕ϲϲϳ͛ ϲ͕Ϯϭϭ͛ ϲ͕Ϯϭϳ͛ ϳ ϬϰͬϭϴͬϮϮ KƉĞŶ ϳ͕ϲϵϲ͛ ϳ͕ϳϬϭ͛ ϲ͕Ϯϰϱ͛ ϲ͕ϮϱϬ͛ ϱ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϬ ϳ͕ϴϯϬ͛ ϳ͕ϴϴϱ͛ ϲ͕ϯϳϭ͛ ϲ͕ϯϵϰ͛ ϱϱ Ϯ͟ ϭϮͬϭϭͬϬϱ KƉĞŶ ϳ͕ϴϰϰ͛ ϳ͕ϴϱϰ͛ ϲ͕ϯϴϰ͛ ϲ͕ϯϵϯ͛ ϭϬ ϮͲϭͬϮ͟ ϭϭͬϭϵͬϬϰ KƉĞŶ ϳ͕ϴϰϰ͛ ϳ͕ϴϱϰ͛ ϲ͕ϯϴϰ͛ ϲ͕ϯϵϯ͛ ϭϬ Ϯ͟ ϱͬϱͬϬϱ KƉĞŶ ϳ͕ϴϲϬ͛ ϳ͕ϴϴϬ͛ ϲ͕ϯϵϵ͛ ϲ͕ϰϭϳ͛ ϮϬ͛ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϳ ϴ͕ϭϵϴ͛ ϴ͕ϮϮϴ͛ ϲ͕ϳϭϴ͛ ϲ͕ϳϰϳ͛ ϯϬ Ϯ͟ ϱͬϰͬϬϱ KƉĞŶ ϴ͕ϭϵϴ͛ ϴ͕Ϯϰϲ͛ ϲ͕ϳϭϴ͛ ϲ͕ϳϰϳ͛ ϰϴ ϮͲϭͬϮ͟ ϭϭͬϭϬΘϭϵͬϬϰ KƉĞŶ ϴ͕Ϯϭϴ ϴ͕Ϯϰϲ͛ ϲ͕ϳϯϳ͛ ϲ͕ϳϲϰ͛ Ϯϴ ϮͲϭͬϮ͟ ϱͬϮͬϬϱ KƉĞŶ ϵͲϱͬϴ͟ĐĞŵĞŶƚũŽď͗ϭϮͲϭͬϰ͟ŚŽůĞ͘ϰϲďďůƐŽĨϭϮ͘ϴηĐůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϭďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘ϮϬďďůƐĐĞŵĞŶƚ ŵŝǆďĂĐŬƚŽƐƵƌĨĂĐĞ ϳ͟ĐĞŵĞŶƚũŽď͗ϴͲϭͬϮ͟ŚŽůĞ͘ϳϱďďůƐŽĨϭϮ͘ϴηůĞĂĚ͕ĂŶĚϭϰďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘EŽůŽƐƐĞƐŶŽƚĞĚ͘sŽůƵŵĞƚƌŝĐ dŽǁŝƚŚϭϬйK,ǁĂƐŚŽƵƚĂƐƐƵŵĞĚсϯϱϬ͛D ϯͲϭͬϮ͟ĐĞŵĞŶƚũŽď͗ϲͲϭͬϴ͟ŚŽůĞ͘ϭϱϱďďůƐŽĨϭϮ͘Ϭη>ŝƚĞĐƌĞƚĞ͘dŽĂƚϰϰϲϬ͛DĨƌŽŵϭϭͬϭͬϬϰ^Dd͘ &/^,ĂƚϴϭϬϮ͛D͗ϮͲϯͬϴ͟ƐƉĞŶƚƉĞƌĨŐƵŶǁŝƚŚŽǀĞƌƐŚŽƚĂŶĚďĂŝƚƐƵďƉůĂŶƚĞĚŽŶƚŽƉ;K>͗ϰϭ͛ͿϰͬϭϬͬϮϭ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/10/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL HVA 10 (PTD 204-186) GPT/PERF 4/18/2022 Please include current contact information if different from above. 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цϲ͕Ϯϭϭ͛ цϲ͕Ϯϭϳ͛ ϳ͚Ϯ͕ϴϬϵ ;ĐĂůĐƵůĂƚĞĚǀŝĂϬ͘ϰϱϮƉƐŝͬ͘Ĩƚ͘ ŐƌĂĚŝĞŶƚ ϰ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶΘĨůŽǁƚĞƐƚǁĞůů ͲůŝŶĞWƌŽĐĞĚƵƌĞ;ŽŶƚŝŶŐĞŶĐǇŝĨǁĂƚĞƌŝƐĞŶĐŽƵŶƚĞƌĞĚĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐͿ ϭ͘ /ĨĂŶǇǌŽŶĞƉƌŽĚƵĐĞƐǁĂƚĞƌŽƌŶĞĞĚƐŝƐŽůĂƚĞĚ͗ Ϯ͘ D/ZhͲ>ŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬϬƉƐŝ͘ ϯ͘ Z/,ĂŶĚƐĞƚƉůƵŐĂďŽǀĞƚŚĞƉĞƌĨŽƌĂƚŝŽŶƐKZƐĞƚƉĂƚĐŚŽǀĞƌƚŚĞǁĞƚƉĞƌĨŽƌĂƚŝŽŶƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇZZ ϬϰͲϮϴͲϮϭ ^,Dd/ ĞĞƉƌĞĞŬ;,ĂƉƉǇsĂůůĞǇͿ tĞůů͗,sͲϭϬ Wd͗ϮϬϰͲϭϴϲ W/ηϱϬͲϮϯϭͲϮϬϬϮϴͲϬϬͲϬϬ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ /dŽƉ ƚŵ ϭϯͲϯͬϴΖ ŽŶĚƵĐƚŽƌ ϳϮͬEͲϴϬͬdͲDŽĚ ϭϮ͘ϯϰϳ ^ƵƌĨ ϳϯΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdͲDŽĚ ϴ͘ϴϯϱ ^ƵƌĨ ϵϰϭ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲDŽĚ ϲ͘Ϯϳϲ ^ƵƌĨ ϯ͕ϴϱϬ͛ ϯͲϭͬϮ͟Η >ŝŶĞƌ ϵ͘Ϯͬ>ͲϴϬͬ/dͲDŽĚ Ϯ͘ϵϵϮ ϯ͕ϲϭϲ͛ϴ͕ϰϭϲΖ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬ/dͲDŽĚ Ϯ͘ϵϵϮ ^ƵƌĨ ϯ͕ϲϲϬ͛ EKd͗ŶŶƵůƵƐ>ŽĂĚĞĚǁŝƚŚϯй<ůƌŝŶĞWůƵƐŽƌƌŽƐŝŽŶ/ŶŚŝďŝƚŽƌ :t>Zzd/> EŽ ĞƉƚŚ //ƚĞŵ ϭ Ϯ͕ϱϬϮ͛Ϯ͘ϴϲϳ͟ϭ͟^ŝĚĞƉŽĐŬĞƚŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶDĂŶĚƌĞůͬDĂĐĐŽ^&KͲ/;t&Ϳ Ϯ ϯ͕ϲϭϲ͛ϰ͘ϬϬ͟ĂŬĞƌyWWĂĐŬĞƌ͕&ůĞǆůŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌΘϴϬͲϰϬ^ĞĂůďŽƌĞ ϯ ϯ͕ϲϲϬ͛ϯ͘ϬϬ͟>ŽĐĂƚŽƌ^ƵďĂŶĚϴϬͲϰϬ^ĞĂů^Ƶď WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d 'ƵŶ ^ŝǌĞ ĂƚĞ ^ƚĂƚƵƐ >ϱϬͲϱϭ ϱ͕ϰϭϰ͛ϱ͕ϰϮϭ͛ϰ͕ϮϯϮ͛ϰ͕Ϯϯϴ͛ϳ Ϯ͟ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϭϰ͛ϱ͕ϰϮϮ͛ϰ͕ϮϯϮ͛ϰ͕Ϯϯϵ͛ϴ ϮͲϯͬϴ͟ϰͬϭϲͬϮϭ KƉĞŶ ϱ͕ϰϭϳ͛ϱ͕ϰϭϵ͛ϰ͕Ϯϯϱ͛ϰ͕Ϯϯϳ͛Ϯ Ϯ͟ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϯϬ͛ϱ͕ϰϯϲ͛ϰ͕Ϯϰϲ͛ϰ͕Ϯϱϭ͛ϲ Ϯ͟ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϯϬ͛ϱ͕ϰϯϳ ϰ͕Ϯϰϲ͛ϰ͕ϮϱϮ͛ϳ ϮͲϯ͘ϴ͟ϰͬϭϲͬϮϭ KƉĞŶ ϱ͕ϰϯϮ͛ϱ͕ϰϯϰ͛ϰ͕Ϯϰϴ͛ϰ͕Ϯϰϵ͛Ϯ Ϯ͟ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϱϲ͛ϱ͕ϰϲϲ͛ϰ͕Ϯϲϴ͛ϰ͕Ϯϳϲ͛ϭϬ Ϯ͟ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϲϬ͛ϱ͕ϰϲϮ͛ϰ͕Ϯϳϭ͛ϰ͕Ϯϳϯ͛Ϯ Ϯ͟ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϳϴ͛ϱ͕ϰϵϴ͛ϰ͕Ϯϴϲ͛ϰ͕ϯϬϯ͛ϮϬ Ϯ͟ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϳϴ͛ϱ͕ϰϵϴ͛ϰ͕Ϯϴϲ͛ϰ͕ϯϬϯ͛ϮϬ ϮͲϯͬϴ͟ϰͬϴͬϮϭ KƉĞŶ ϱ͕ϰϴϳ͛ϱ͕ϰϴϵ͛ϰ͕Ϯϵϰ͛ϰ͕Ϯϵϱ͛Ϯ Ϯ͟ϭϮͬϭϳͬϮϬ KƉĞŶ dͲϭ ϳ͕Ϯϯϲ͛ϳ͕Ϯϱϯ͛ϱ͕ϴϭϵ͛ϱ͕ϴϯϱ͛ϭϳ ϮͲϯͬϴ͟ϭͬϭϴͬϮϬ KƉĞŶ dͲϮϳ͕ϯϯϰ͛ϳ͕ϯϰϭ͛ϱ͕ϵϬϵ͛ϱ͕ϵϭϲ͛ϳ ϮͲϯͬϴ͟ϭͬϭϳͬϮϬ KƉĞŶ dͲϲ ϳ͕ϰϴϭ͛ϳ͕ϱϬϲ͛ϲ͕Ϭϰϱ͛ϲ͕Ϭϲϴ͛Ϯϱ ϮͲϯͬϴ͟ϭϮͬϭϱͬϭϱ KƉĞŶ ϳ͕ϱϭϳ͛ϳ͕ϱϮϬ͛ϲ͕Ϭϳϴ͛ϲ͕Ϭϴϭ͛ϯ ϮͲϯͬϴ͟ϰͬϭϲͬϮϭ KƉĞŶ dͲϳ ϳ͕ϱϰϲ͛ϳ͕ϱϳϭ͛ϲ͕ϭϬϱ͛ϲ͕ϭϮϴ͛Ϯϱ ϮͲϯͬϴ͟ϭϮͬϭϱͬϭϱ KƉĞŶ ϳ͕ϲϵϲ͛ϳ͕ϳϬϭ͛ϲ͕Ϯϰϱ͛ϲ͕ϮϱϬ͛ϱ ϮͲϯͬϴ͟ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϬ ϳ͕ϴϯϬ͛ϳ͕ϴϴϱ͛ϲ͕ϯϳϭ͛ϲ͕ϯϵϰ͛ϱϱ Ϯ͟ϭϮͬϭϭͬϬϱ KƉĞŶ ϳ͕ϴϰϰ͛ϳ͕ϴϱϰ͛ϲ͕ϯϴϰ͛ϲ͕ϯϵϯ͛ϭϬ ϮͲϭͬϮ͟ϭϭͬϭϵͬϬϰ KƉĞŶ ϳ͕ϴϰϰ͛ϳ͕ϴϱϰ͛ϲ͕ϯϴϰ͛ϲ͕ϯϵϯ͛ϭϬ Ϯ͟ϱͬϱͬϬϱ KƉĞŶ ϳ͕ϴϲϬ͛ϳ͕ϴϴϬ͛ϲ͕ϯϵϵ͛ϲ͕ϰϭϳ͛ϮϬ͛ϮͲϯͬϴ͟ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϳ ϴ͕ϭϵϴ͛ϴ͕ϮϮϴ͛ϲ͕ϳϭϴ͛ϲ͕ϳϰϳ͛ϯϬ Ϯ͟ϱͬϰͬϬϱ KƉĞŶ ϴ͕ϭϵϴ͛ϴ͕Ϯϰϲ͛ϲ͕ϳϭϴ͛ϲ͕ϳϰϳ͛ϰϴ ϮͲϭͬϮ͟ϭϭͬϭϬΘϭϵͬϬϰ KƉĞŶ ϴ͕Ϯϭϴ ϴ͕Ϯϰϲ͛ϲ͕ϳϯϳ͛ϲ͕ϳϲϰ͛Ϯϴ ϮͲϭͬϮ͟ϱͬϮͬϬϱ KƉĞŶ ϵͲϱͬϴ͟ĐĞŵĞŶƚũŽď͗ϭϮͲϭͬϰ͟ŚŽůĞ͘ϰϲďďůƐŽĨϭϮ͘ϴηĐůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϭďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘ϮϬďďůƐĐĞŵĞŶƚ ŵŝǆďĂĐŬƚŽƐƵƌĨĂĐĞ ϳ͟ĐĞŵĞŶƚũŽď͗ϴͲϭͬϮ͟ŚŽůĞ͘ϳϱďďůƐŽĨϭϮ͘ϴηůĞĂĚ͕ĂŶĚϭϰďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘EŽůŽƐƐĞƐŶŽƚĞĚ͘sŽůƵŵĞƚƌŝĐ dŽǁŝƚŚϭϬйK, ǁĂƐŚŽƵƚĂƐƐƵŵĞĚсϯϱϬ͛D ϯͲϭͬϮ͟ĐĞŵĞŶƚũŽď͗ϲͲϭͬϴ͟ŚŽůĞ͘ϭϱϱďďůƐŽĨϭϮ͘Ϭη>ŝƚĞĐƌĞƚĞ͘dŽĂƚϰϰϲϬ͛DĨƌŽŵϭϭͬϭͬϬϰ^Dd͘ &/^, ĂƚϴϭϬϮ͛D͗ϮͲϯͬϴ͟ƐƉĞŶƚƉĞƌĨŐƵŶǁŝƚŚ ŽǀĞƌƐŚŽƚĂŶĚďĂŝƚƐƵďƉůĂŶƚĞĚŽŶƚŽƉ;K>͗ϰϭ͛ͿϰͬϭϬͬϮϭ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇ:>>ϬϯͬϮϵͬϮϮ WZKWK^ ĞĞƉƌĞĞŬ;,ĂƉƉǇsĂůůĞǇͿ tĞůů͗,sͲϭϬ Wd͗ϮϬϰͲϭϴϲ W/ηϱϬͲϮϯϭͲϮϬϬϮϴͲϬϬͲϬϬ dсϴ͕ϰϮϬ͛;DͿͬϲ͕ϵϯϬ͛;dsͿ Z<͗D^>сϭϲ͘ϰ͛ ϳ͟ Ϯ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ ϭ dͲϭϬ ϯͲϭͬϮ͟ Wdсϴ͕ϯϰϴ͛;DͿͬϲ͕ϴϲϭ͛;dsͿ dͲϭϳ ϯ dͲϳ dͲϲ dͲϮ dͲϭ %(/ dKΛϰ͕ϰϲϬ͛ ;ϭϭͬϭͬϬϰ^DdͿ %(/ %(/ %(/ %(/ %(/ %(/ dͲϯ ^/E'd/> ^ŝǌĞ dǇƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ / dŽƉ ƚŵ ϭϯͲϯͬϴΖ ŽŶĚƵĐƚŽƌ ϳϮͬEͲϴϬͬdͲDŽĚ ϭϮ͘ϯϰϳ ^ƵƌĨ ϳϯΖ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdͲDŽĚ ϴ͘ϴϯϱ ^ƵƌĨ ϵϰϭ ϳΗ /ŶƚĞƌŵĞĚŝĂƚĞ Ϯϲͬ>ͲϴϬͬdͲDŽĚ ϲ͘Ϯϳϲ ^ƵƌĨ ϯ͕ϴϱϬ͛ ϯͲϭͬϮ͟Η >ŝŶĞƌ ϵ͘Ϯͬ>ͲϴϬͬ/dͲDŽĚ Ϯ͘ϵϵϮ ϯ͕ϲϭϲ͛ ϴ͕ϰϭϲΖ dh/E'd/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘Ϯͬ>ͲϴϬͬ/dͲDŽĚ Ϯ͘ϵϵϮ ^ƵƌĨ ϯ͕ϲϲϬ͛ EKd͗ŶŶƵůƵƐ>ŽĂĚĞĚǁŝƚŚϯй<ůƌŝŶĞWůƵƐŽƌƌŽƐŝŽŶ/ŶŚŝďŝƚŽƌ :t>Zzd/> EŽ ĞƉƚŚ / /ƚĞŵ ϭ Ϯ͕ϱϬϮ͛ Ϯ͘ϴϲϳ͟ ϭ͟^ŝĚĞƉŽĐŬĞƚŚĞŵŝĐĂů/ŶũĞĐƚŝŽŶDĂŶĚƌĞůͬDĂĐĐŽ^&KͲ/;t&Ϳ Ϯ ϯ͕ϲϭϲ͛ ϰ͘ϬϬ͟ ĂŬĞƌyWWĂĐŬĞƌ͕&ůĞǆůŽĐŬ>ŝŶĞƌ,ĂŶŐĞƌΘϴϬͲϰϬ^ĞĂůďŽƌĞ ϯ ϯ͕ϲϲϬ͛ ϯ͘ϬϬ͟ >ŽĐĂƚŽƌ^ƵďĂŶĚϴϬͲϰϬ^ĞĂů^Ƶď WZ&KZd/KEd/> ^ĂŶĚƐ dŽƉ;DͿ ƚŵ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d 'ƵŶ ^ŝǌĞ ĂƚĞ ^ƚĂƚƵƐ >ϱϬͲϱϭ ϱ͕ϰϭϰ͛ ϱ͕ϰϮϭ͛ ϰ͕ϮϯϮ͛ ϰ͕Ϯϯϴ͛ ϳ Ϯ͟ ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϭϰ͛ ϱ͕ϰϮϮ͛ ϰ͕ϮϯϮ͛ ϰ͕Ϯϯϵ͛ ϴ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ ϱ͕ϰϭϳ͛ ϱ͕ϰϭϵ͛ ϰ͕Ϯϯϱ͛ ϰ͕Ϯϯϳ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϯϬ͛ ϱ͕ϰϯϲ͛ ϰ͕Ϯϰϲ͛ ϰ͕Ϯϱϭ͛ ϲ Ϯ͟ ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϯϬ͛ ϱ͕ϰϯϳ ϰ͕Ϯϰϲ͛ ϰ͕ϮϱϮ͛ ϳ ϮͲϯ͘ϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ ϱ͕ϰϯϮ͛ ϱ͕ϰϯϰ͛ ϰ͕Ϯϰϴ͛ ϰ͕Ϯϰϵ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϱϲ͛ ϱ͕ϰϲϲ͛ ϰ͕Ϯϲϴ͛ ϰ͕Ϯϳϲ͛ ϭϬ Ϯ͟ ϭϮͬϭϴͬϮϬ KƉĞŶ ϱ͕ϰϲϬ͛ ϱ͕ϰϲϮ͛ ϰ͕Ϯϳϭ͛ ϰ͕Ϯϳϯ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϳϴ͛ ϱ͕ϰϵϴ͛ ϰ͕Ϯϴϲ͛ ϰ͕ϯϬϯ͛ ϮϬ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ ϱ͕ϰϳϴ͛ ϱ͕ϰϵϴ͛ ϰ͕Ϯϴϲ͛ ϰ͕ϯϬϯ͛ ϮϬ ϮͲϯͬϴ͟ ϰͬϴͬϮϭ KƉĞŶ ϱ͕ϰϴϳ͛ ϱ͕ϰϴϵ͛ ϰ͕Ϯϵϰ͛ ϰ͕Ϯϵϱ͛ Ϯ Ϯ͟ ϭϮͬϭϳͬϮϬ KƉĞŶ >ͺϱϱ цϱ͕ϲϬϲ͛ цϱ͕ϲϭϱ͛ цϰ͕Ϯϵϯ͛ цϰ͕ϰϬϭ͛ цϵ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >ͺϳϬ цϱ͕ϴϮϰ͛ цϱ͕ϴϯϱ͛ цϰ͕ϱϳϴ͛ цϰ͕ϱϴϳ͛ цϭϭ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >ͺϳϴ цϱ͕ϵϴϱ͛ цϱ͕ϵϵϯ͛ цϰ͕ϳϭϱ͛ цϰ͕ϳϮϭ͛ цϴ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >ͺϵϮ цϲ͕ϯϮϳ͛ цϲ͕ϯϯϵ͛ цϱ͕ϬϬϵ͛ цϱ͕Ϭϭϵ͛ цϭϮ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >ͺϵϯ цϲ͕ϯϱϱ͛ цϲ͕ϯϲϵ͛ цϱ͕Ϭϯϯ͛ цϱ͕Ϭϰϲ͛ цϭϰ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ >ͺϭϯϮ цϲ͕ϵϵϮ͛ цϲ͕ϵϵϵ͛ цϱ͕ϱϵϳ͛ цϱ͕ϲϬϰ͛ цϳ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ dͲϭ ϳ͕Ϯϯϲ͛ ϳ͕Ϯϱϯ͛ ϱ͕ϴϭϵ͛ ϱ͕ϴϯϱ͛ ϭϳ ϮͲϯͬϴ͟ ϭͬϭϴͬϮϬ KƉĞŶ dͲϮ ϳ͕ϯϯϰ͛ ϳ͕ϯϰϭ͛ ϱ͕ϵϬϵ͛ ϱ͕ϵϭϲ͛ ϳ ϮͲϯͬϴ͟ ϭͬϭϳͬϮϬ KƉĞŶ dͲϯƵ цϳ͕ϯϱϰ͛ цϳ͕ϯϲϬ͛ цϱ͕ϵϮϴ͛ цϱ͕ϵϯϯ͛ цϲ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ dͲϯů цϳ͕ϯϲϱ͛ цϳ͕ϯϴϮ͛ цϱ͕ϵϯϴ͛ цϱ͕ϵϱϯ͛ цϭϳ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ dͲϲƵ цϳ͕ϰϯϴ͛ цϳ͕ϰϰϮ͛ цϲ͕ϬϬϲ͛ цϲ͕ϬϬϵ͛ цϰ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ dͲϲů цϳ͕ϰϱϳ͛ цϳ͕ϰϲϭ͛ цϲ͕ϬϮϯ͛ цϲ͕ϬϮϲ͛ цϰ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ dͲϲ ϳ͕ϰϴϭ͛ ϳ͕ϱϬϲ͛ ϲ͕Ϭϰϱ͛ ϲ͕Ϭϲϴ͛ Ϯϱ ϮͲϯͬϴ͟ ϭϮͬϭϱͬϭϱ KƉĞŶ dͲϲ ϳ͕ϱϭϳ͛ ϳ͕ϱϮϬ͛ ϲ͕Ϭϳϴ͛ ϲ͕Ϭϴϭ͛ ϯ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϳ ϳ͕ϱϰϲ͛ ϳ͕ϱϳϭ͛ ϲ͕ϭϬϱ͛ ϲ͕ϭϮϴ͛ Ϯϱ ϮͲϯͬϴ͟ ϭϮͬϭϱͬϭϱ KƉĞŶ dͲϳƵ цϳ͕ϲϲϬ͛ цϳ͕ϲϲϳ͛ цϲ͕Ϯϭϭ͛ цϲ͕Ϯϭϳ͛ цϳ &ƵƚƵƌĞ WƌŽƉŽƐĞĚ ϳ͕ϲϵϲ͛ ϳ͕ϳϬϭ͛ ϲ͕Ϯϰϱ͛ ϲ͕ϮϱϬ͛ ϱ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϬ ϳ͕ϴϯϬ͛ ϳ͕ϴϴϱ͛ ϲ͕ϯϳϭ͛ ϲ͕ϯϵϰ͛ ϱϱ Ϯ͟ ϭϮͬϭϭͬϬϱ KƉĞŶ ϳ͕ϴϰϰ͛ ϳ͕ϴϱϰ͛ ϲ͕ϯϴϰ͛ ϲ͕ϯϵϯ͛ ϭϬ ϮͲϭͬϮ͟ ϭϭͬϭϵͬϬϰ KƉĞŶ ϳ͕ϴϰϰ͛ ϳ͕ϴϱϰ͛ ϲ͕ϯϴϰ͛ ϲ͕ϯϵϯ͛ ϭϬ Ϯ͟ ϱͬϱͬϬϱ KƉĞŶ ϳ͕ϴϲϬ͛ ϳ͕ϴϴϬ͛ ϲ͕ϯϵϵ͛ ϲ͕ϰϭϳ͛ ϮϬ͛ ϮͲϯͬϴ͟ ϰͬϭϲͬϮϭ KƉĞŶ dͲϭϳ ϴ͕ϭϵϴ͛ ϴ͕ϮϮϴ͛ ϲ͕ϳϭϴ͛ ϲ͕ϳϰϳ͛ ϯϬ Ϯ͟ ϱͬϰͬϬϱ KƉĞŶ ϴ͕ϭϵϴ͛ ϴ͕Ϯϰϲ͛ ϲ͕ϳϭϴ͛ ϲ͕ϳϰϳ͛ ϰϴ ϮͲϭͬϮ͟ ϭϭͬϭϬΘϭϵͬϬϰ KƉĞŶ ϴ͕Ϯϭϴ ϴ͕Ϯϰϲ͛ ϲ͕ϳϯϳ͛ ϲ͕ϳϲϰ͛ Ϯϴ ϮͲϭͬϮ͟ ϱͬϮͬϬϱ KƉĞŶ ϵͲϱͬϴ͟ĐĞŵĞŶƚũŽď͗ϭϮͲϭͬϰ͟ŚŽůĞ͘ϰϲďďůƐŽĨϭϮ͘ϴηĐůĂƐƐ'ůĞĂĚ͕ĂŶĚϯϭďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘ϮϬďďůƐĐĞŵĞŶƚ ŵŝǆďĂĐŬƚŽƐƵƌĨĂĐĞ ϳ͟ĐĞŵĞŶƚũŽď͗ϴͲϭͬϮ͟ŚŽůĞ͘ϳϱďďůƐŽĨϭϮ͘ϴηůĞĂĚ͕ĂŶĚϭϰďďůƐŽĨϭϱ͘ϴηĐůĂƐƐ'ƚĂŝů͘EŽůŽƐƐĞƐŶŽƚĞĚ͘sŽůƵŵĞƚƌŝĐ dŽǁŝƚŚϭϬйK,ǁĂƐŚŽƵƚĂƐƐƵŵĞĚсϯϱϬ͛D ϯͲϭͬϮ͟ĐĞŵĞŶƚũŽď͗ϲͲϭͬϴ͟ŚŽůĞ͘ϭϱϱďďůƐŽĨϭϮ͘Ϭη>ŝƚĞĐƌĞƚĞ͘dŽĂƚϰϰϲϬ͛DĨƌŽŵϭϭͬϭͬϬϰ^Dd͘ &/^,ĂƚϴϭϬϮ͛D͗ϮͲϯͬϴ͟ƐƉĞŶƚƉĞƌĨŐƵŶǁŝƚŚŽǀĞƌƐŚŽƚĂŶĚďĂŝƚƐƵďƉůĂŶƚĞĚŽŶƚŽƉ;K>͗ϰϭ͛ͿϰͬϭϬͬϮϭ 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 and return one copy of this transmittal or FAX to 907 564-4424 Received By: Date: Hilcorp North Slope, LLC Date: 06/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type Logging Company HVA-10 502312002800 204186 4/16/2021 PERF GAMMA RAY / GPT Yellowjacket HVB-17 502312004900 215189 2/1/2021 PERF/GPT Yellowjacket HVB-17 502312004900 215189 4/1/2021 PERF GAMMA RAY / GPT Yellowjacket Please include current contact information if different from above. Received By: 06/28/2021 37' (6HW By Abby Bell at 12:10 pm, Jun 28, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,420 feet N/A feet true vertical 6,930 feet see schematic feet Effective Depth measured 8,348 feet 3,616 feet true vertical 6,861 feet 2,836 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,661' MD 2,866' TVD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr; N/A 3,616' MD 2,836' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ryan Rupert Authorized Title:Operations Manager Contact Email: Contact Phone:777-8503 WINJ WAG 324 Water-Bbl MD 73' 941' 4 Oil-Bbl measured true vertical Packer 3-1/2"8,416' 2,995' 6,926' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Deep Creek Field - HV Beluga / Tyonek GasN/A measured TVD Tubing Pressure 921 Happy Valley A-10 N/A FEE CIRI (C-061590) 3,850' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-186 50-231-20028-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-142 92 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 311 0 Representative Daily Average Production or Injection Data 73' 941' 3,850' 4,785' Conductor Surface Intermediate Production 10,540psi Casing Structural 13-3/8" 9-5/8" 7" Length 7,240psi 5,750psi Collapse 2,670psi 3,090psi 5,410psi ryan.rupert@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 5,380psi 10,160psi 73' 924' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 8:27 am, May 17, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.05.14 15:31:50 -08'00' Taylor Wellman (2143) DSR-5/17/21 RBDMS HEW 5/17/2021 BJM 8/10/21 SFD 5/20/2021 Rig Start Date End Date E-Line 4/7/21 4/16/21 04/10/2021 - Saturday ARRIVE AT H.V. OFFICE, PERMIT, JSA. RIG UP .125 S/L & EXTRA LUB, P.T. W/ WELL BORE 250 PSI. RIH W/ 2.6'' LIB TO 5,452'KB W/T POOH - CLEAR ROPE SOCKET INDICATION W/ NO WIRE. RIH W/ 1-3/8" JDC W/ 2.25'' BELL GUIDE TO 5,452'KB, LATCH, DO 3 1,700# JAR LICKS, COMES FREE. POOH - JDC SHEARED AND DOGS SCHUCKED. TALK W/ LEAD, LAY DOWN LUB, SWAP OVER TO .160 WIRE RIH W/ 2-7/8" GU W/ 2.25' BAIT SUB W/ 2.32'' OVERSHOT TO 5,446'KBM W/T DO 1 2,000# JAR LICK COMES FREE POOH - GU SHEARED. RIH W/ 2-7/8" GS TO 5,444'KB, DO 4 3,500# JAR LICKS COMES FREE POOH - GETS STUCK IN TREE. TRY LIGHTLY HAND SPANGING, NO MOVEMENT, RIG TOOLS BACK IN HOLE TO, SIT DOWN AT 5,430' KB W/T FALLS TO 8,142'KB W/T WONT FALL FURTHER, SHEAR OFF. POOH. RIG DOWN. DROP EQUIPMENT OFF AT PAXTON, END TICKET. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name HVA-10 50-231-22028-00-00 204-186 04/07/2021 - Wednesday Sign in. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. Flowing 90 psi. RIH w/GPT tool, tie into Town log and tag at 8,214'. Logged at 100 fpm from 8,214' to 5,000'. Found fluid level at 7,124'. Called town and was told we could stop logging at 5,000'. Send log to town to check correlation. POOH Flowing Pressure 90.4 psi. Rig down off tree, close valves and put night cap on. Will be back in AM. 04/08/2021 - Thursday Arrive at HVA pad. Got a call from HES that they were stuck about 4 miles from pad. Went down and brought HES engr back to pad to get there F-550 truck to pull it out. Pulled pickup out. No damage or spill. Get back to pad. PTW and JSA. Rig lubricator back up. PT to 250 psi low and 2,500 psi high 2,500 psi. RIH w/ 2-3/8" x 20' Geo HC, 5 spf, 60 deg phase and tie into yesterday's GPT log sent back. Run correlation and send back to town. Told to shift log up 1'. Shift up 1 ', spot and fired gun from 5,478' to 5,498' with 90.1 psi. After 5 min - 90.1 psi. Tools were stuck as soon as fired. Worked tools up to 3,000 lb. Shut well in and built up to 220 psi. and ripped open well. No good. Built pressure up to approx. 250 psi , pulled tool weight to 3,300 lb and rip it open again. Justin with HES called and said that the Geo 2-3/8" charges were changed to shoot in fluid only and we were in gas. That would split gun. Decision made to pull out of rope socket. Scoped down crane and pulled to 4,000 lb before pulling out of rope socket. POOH. and left tools in well. HES having trouble with computer and will send tool drawing later today. Rig down off well, secure well and turn back over to field. Daily Operations: fired gun from 5,478' to 5,498' W/T FALLS TO 8,142'KB W/T WONT FALL FURTHER, SHEAR OFF. POOH. Rig Start Date End Date E-Line 4/7/21 4/16/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name HVA-10 50-231-22028-00-00 204-186 Daily Operations: 04/16/2021- Friday YellowJacket E-line arrive location and conduct JSA and approve PTW. PT lubricator to 250/3,000 psi Open well with well flowing, TP = 90 psi. RIH with 2-3/8" x 20' dummy perf gun. Drift to 8,000'. POOH. MU Perf guns 1 & 2. Perf guns are 2-3/8", 5 spf, 60 deg phasing, razor charges. GR/CCL to TS of Gun #1 = 17', GR/CCL to TS of Gun #2 = 10'. Run correlation log and send to Geo, on depth. Well flowing TP = 90 psi. Perforate T-10 from 7,860' - 7,880' MD. Perforate T-7 from 7,696' - 7,701' MD. POOH. Shots fired. Gun is wet. MU Perf guns 3, 4, & 5. Perf guns are 2-3/8", 5 spf, 60 deg phasing, razor charges. GR/CCL to TS of gun #3 = 32.5', GR/CCL to TS of gun #4 = 21', GR/CCL to TS of gun #5 = 11'. Run correlation log for gun #3 and send to Geo, subtract 1'. Well flowing TP = 90 psi. Perforate T-6 from 7,517' - 7520' MD Run correlation log for guns #4 & 5, send to Geo, add 1'. Well flowing TP = 90 psi. Perforate Bel 50/51 from 5,430' - 5,437'. Perforate Bel 50/51 from 5,414' - 5,422'. POOH. Shots fired. Gun is wet. MU and RIH with GPT toolstring. Log from surface to 7,950' with well flowing. POOH. RDMO. Perforate T-6 from 7,517' - 7520' MD Perforate Bel 50/51 from 5,430' - 5,437' Perforate Bel 50/51 from 5,414' - 5,422'. Perforate T-10 from 7,860' - 7,880' MD. Perforate T-7 from 7,696' - 7,701' MD. _____________________________________________________________________________________ Updated by CRR 04-28-21 SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 PTD: 204-186 API # 50-231-20028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8' Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8" Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7" Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”" Liner 9.2 / L-80 / IBT-Mod 2.992 3,616’ 8,416' TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,660’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth ID Item 1 2,502’ 2.867” 1” Sidepocket Chemical Injection Mandrel / Macco SFO-CI (WFD) 2 3,616’ 4.00” Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,660’ 3.00” Locator Sub and 80-40 Seal Sub PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Gun Size Date Status BEL 50-51 5,414’ 5,421’ 4,232’ 4,238’ 7 2” 12/18/20 Open 5,414’ 5,422’ 4,232’ 4,239’ 8 2-3/8” 4/16/21 Open 5,417’ 5,419’ 4,235’ 4,237’ 2 2” 12/17/20 Open 5,430’ 5,436’ 4,246’ 4,251’ 6 2” 12/18/20 Open 5,430’ 5,437 4,246’ 4,252’ 7 2-3.8” 4/16/21 Open 5,432’ 5,434’ 4,248’ 4,249’ 2 2” 12/17/20 Open 5,456’ 5,466’ 4,268’ 4,276’ 10 2” 12/18/20 Open 5,460’ 5,462’ 4,271’ 4,273’ 2 2” 12/17/20 Open 5,478’ 5,498’ 4,286’ 4,303’ 20 2” 12/17/20 Open 5,478’ 5,498’ 4,286’ 4,303’ 20 2-3/8” 4/8/21 Open 5,487’ 5,489’ 4,294’ 4,295’ 2 2” 12/17/20 Open T-1 7,236’ 7,253’ 5,819’ 5,835’ 17 2-3/8” 1/18/20 Open T-2B 7,334’ 7,341’ 5,909’ 5,916’ 7 2-3/8” 1/17/20 Open T-6 7,481’ 7,506’ 6,045’ 6,068’ 25 2-3/8” 12/15/15 Open 7,517’ 7,520’ 6,078’ 6,081’ 3 2-3/8” 4/16/21 Open T-7 7,546’ 7,571’ 6,105’ 6,128’ 25 2-3/8” 12/15/15 Open 7,696’ 7,701’ 6,245’ 6,250’ 5 2-3/8” 4/16/21 Open T-10 7,830’ 7,885’ 6,371’ 6,394’ 55 2” 12/11/05 Open 7,844’ 7,854’ 6,384’ 6,393’ 10 2-1/2” 11/19/04 Open 7,844’ 7,854’ 6,384’ 6,393’ 10 2” 5/5/05 Open 7,860’ 7,880’ 6,399’ 6,417’ 20’ 2-3/8” 4/16/21 Open T-17 8,198’ 8,228’ 6,718’ 6,747’ 30 2” 5/4/05 Open 8,198’ 8,246’ 6,718’ 6,747’ 48 2-1/2” 11/10&19/04 Open 8,218 8,246’ 6,737’ 6,764’ 28 2-1/2” 5/2/05 Open 9-5/8” cement job: 12-1/4” hole. 46bbls of 12.8# class G lead, and 31bbls of 15.8# class G tail. 20bbls cement mix back to surface 7” cement job: 8-1/2” hole. 75bbls of 12.8# lead, and 14bbls of 15.8# class G tail. No losses noted. Volumetric ToC with 10% OH washout assumed = 350’ MD 3-1/2” cement job: 6-1/8” hole. 155bbls of 12.0# Litecrete. ToC at 4460’ MD from 11/1/04 SCMT. FISH at 8102’ MD: 2-3/8” spent perf gun with overshot and bait sub planted on top (OAL: 41’) 4/10/21 5,414’5,422’ 4,232’4,239’8 2-3/8” 4/16/21 Open ,,,,//p 7,860’7,880’ 6,399’6,417’20’2-3/8”4/16/21 Open T-6 7,517’7,520’ 6,078’6,081’3 2-3/8”4/16/21 Open T-6 5,478’ 5,498’ 4,286’4,303’20 2-3/8” 4/8/21 Open ,,,,//p T-7 7,696’7,701’ 6,245’6,250’5 2-3/8”4/16/21 Open T7 L50-BE 51 5,430’5,437 4,246’4,252’7 2-3.8”4/16/21 Open L50BE 51 p ’’’’”// 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 /Patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 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 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,420'8,231' (fill) Casing Collapse Structural Conductor 2,670psi Surface 3,090psi Intermediate 5,410psi Production 10,540psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ryan Rupert Operations Manager Contact Email: Contact Phone: 301-1736 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ryan.rupert@hilcorp.com 6,930'8,348'6,861'1,835psi N/A Baker ZXP Packer; N/A 3,616' MD / 2,836' TVD; N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE CIRI (C-061590) 204-186 50-231-20028-00-00 Happy Valley A-10 Deep Creek Field - HV Beluga / Tyonek Gas Length Size CO 553A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.2# L-80 TVD Burst 3660 10,160psi MD 7,240psi 5,380psi 5,750psi 73' 924' 2,995' 73' 941' 6,926'3-1/2" 13-3/8" 9-5/8" 73' 7"3,850' 941' 8,416' Perforation Depth MD (ft): 3,850' See Attached Schematic 4,800' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: April 2, 2021 3-1/2" m n P s 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:51 am, Mar 22, 2021 321-142 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.22 08:30:57 -08'00' Taylor Wellman (2143) DSR-3/22/21SFD 3/22/2021 10-404 BJM 3/26/21 Comm. 3/30/21 dts 3/26/2021 JLC 3/30/2021 RBDMS HEW 3/30/2021 Adperf/Reperf Well: HVA-10 Date: 3/22/2021 Well Name:HVA-10 API Number:50-231-20028-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:204-186 First Call Engineer:Ryan Rupert (907) 777-8503 (O)(907) 301-1736 (C) Second Call Engineer:Ted Kramer (907) 777-8420 (O)(985) 867-0665 (C) Maximum Expected BHP:~ 2459 psi @ 6,244’ TVD (2016 RFT in T-7 from HBV-17) Max. Potential Surface Pressure:~ 1835 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface). Well Summary HVA-10 has been a steady producer at Happy Valley since it was drilled in 2004. The well has had mixed success with adperfs and reperfs since then. The well is now flowing at ~350MCF at 90 psi FTP with 0-2 bwpd production. The BEL-50/51 interval was perf’d for the first time in this well in Dec-2020. Production didn’t chance much after this add. A Flowing P/T survey was run afterwards, and little or no contribution was seen from these new perfs. The Dec-2020 perfs were shot with 2” guns and 1000+psi underbalance while the well was SI. Although inconclusive historically, most of the perfs that have worked were shot while flowing with 1000+psi underbalance and 2-3/8” or 2-1/2” guns. That’s what we’ll aim for in this intervention. The plan for this project is to perforate and reperforate existing and additional sands. Notes Regarding Wellbore Condition x Min ID = 2.867” at 2502’ MD (Drift ID through CI mandrel) x Max inclination = 50 degrees at 1920’ md x Drifts o 12/18/20: EL tagged bottom at 8231’ MD after perforating with a GPT+6’+7’ gun assembly (2” Guns) o 1/18/20: GPT log tagged at 8224’ MD. No water was logged. EL also ran down to 7253’ MD with 17’ x 2-3/8” guns (no tag) Risks x Nitrogen o Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. o Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during this job) o Ensure all crews are aware of stop work authority Adperf/Reperf Well: HVA-10 Date: 3/22/2021 EL Perforating 1. MIRU EL 2. PT BOP equipment to 250 psi Low / 2,500 psi High. 3. PU GPT and perform a flowing P/T survey from PBTD to surface. (want a corrected tag of PBTD) 4. Rig up perf guns (Likely 2-3/8” 4-6 spf) 5. RIH and perforate the sands listed in the table below: Consult with OE for what WHP to use. Base plan will be to shoot well flowing. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Anthony McConkey: RE - 529-6199 ii. Matthew Petrowsky: Geo – 814-421-6753 6.RD E-Line Unit and turn well over to production. Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 4,000 psi high 2. RIH W/ GPT tool and find fluid level 3. RU Nitrogen Truck and push water back into formation 4. Use GPT tool to confirm water level is below target interval 5. Once fluid level is below target interval, RIH and set 3-1/2” Patch or plug 6. RD E-Line Unit and turn well over to production. Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations Sand Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Total Footage (MD) Expected BHP (psi) BEL 50/51 ±5414'±5422'±4232'±4239'8'1870psi (0.44 psi/ft.) BEL 50/51 ±5430'±5437'±4246'±4252'7'1870psi (0.44 psi/ft.) BEL 50/51 ±5478'±5498'±4286'±4303'20'1870psi (0.44 psi/ft.) T-6 ±7516'±7520'±6077'±6081'4'1,640psi (5/9/2016 RFT in HVB-17) T-7 ±7695'±7701'±6244'±6250'6'2,459psi (5/9/2016 RFT in HVB-17) T-10 ±7860'±7880'±6399'±6417'20'2,455psi (5/9/2016 RFT in HVB-17) T-17 ±8200'±8220'±6720'±6739'20'687psi (5/9/2016 RFT in HVB-17) _____________________________________________________________________________________ Updated by CRR 03-22-21 SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 PTD: 204-186 API #50-231-20028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8'Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8"Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7"Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”"Liner 9.2 / L-80 / IBT-Mod 2.992 3,616’8,416' TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,660’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth ID Item 1 2,502’2.867”1” Sidepocket Chemical Injection Mandrel / Macco SFO-CI (WFD) 2 3,616’4.00”Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,660’3.00”Locator Sub and 80-40 Seal Sub PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD) Btm (TVD)FT Gun Size Date Status BEL 50-51 5,414’5,421’4,232’4,238’7 2”12/18/20 Open 5,417’5,419’4,235’4,237’2 2”12/17/20 Open 5,430’5,436’4,246’4,251’6 2”12/18/20 Open 5,432’5,434’4,248’4,249’2 2”12/17/20 Open 5,456’5,466’4,268’4,276’10 2”12/18/20 Open 5,460’5,462’4,271’4,273’2 2”12/17/20 Open 5,478’5,498’4,286’4,303’20 2”12/17/20 Open 5,487’5,489’4,294’4,295’2 2”12/17/20 Open T-1 7,236’7,253’5,819’5,835’17 2-3/8”1/18/20 Open T-2B 7,334’7,341’5,909’5,916’7 2-3/8”1/17/20 Open T-6 7,481’7,506’6,045’6,068’25 2-3/8”12/15/15 Open T-7 7,546’7,571’6,105’6,128’25 2-3/8”12/15/15 Open T-10 7,830’7,885’6,371’6,394’55 2”12/11/05 Open 7,844’7,854’6,384’6,393’10 2-1/2”11/19/04 Open 7,844’7,854’6,384’6,393’10 2”5/5/05 Open T-17 8,198’8,228’6,718’6,747’30 2”5/4/05 Open 8,198’8,246’6,718’6,747’48 2-1/2”11/10&19/04 Open 8,218 8,246’6,737’6,764’28 2-1/2”5/2/05 Open 9-5/8” cement job:12-1/4” hole. 46bbls of 12.8# class G lead, and 31bbls of 15.8# class G tail. 20bbls cement mix back to surface 7” cement job:8-1/2” hole. 75bbls of 12.8# lead, and 14bbls of 15.8# class G tail. No losses noted. Volumetric ToC with 10% OH washout assumed = 350’ MD 3-1/2” cement job:6-1/8” hole. 155bbls of 12.0# Litecrete. ToC at 4460’ MD from 11/1/04 SCMT. _____________________________________________________________________________________ Updated by CRR 03-22-21 PROPOSED SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 PTD: 204-186 API #50-231-20028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8'Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8"Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7"Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”"Liner 9.2 / L-80 / IBT-Mod 2.992 3,616’8,416' TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,660’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth ID Item 1 2,502’2.867”1” Sidepocket Chemical Injection Mandrel / Macco SFO-CI (WFD) 2 3,616’4.00”Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,660’3.00”Locator Sub and 80-40 Seal Sub PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD) Btm (TVD)FT Gun Size Date Status Proposed perfs and reperfs per sundry BEL 50-51 5,414’5,421’4,232’4,238’7 2”12/18/20 Open 5,417’5,419’4,235’4,237’2 2”12/17/20 Open 5,430’5,436’4,246’4,251’6 2”12/18/20 Open 5,432’5,434’4,248’4,249’2 2”12/17/20 Open 5,456’5,466’4,268’4,276’10 2”12/18/20 Open 5,460’5,462’4,271’4,273’2 2”12/17/20 Open 5,478’5,498’4,286’4,303’20 2”12/17/20 Open 5,487’5,489’4,294’4,295’2 2”12/17/20 Open T-1 7,236’7,253’5,819’5,835’17 2-3/8”1/18/20 Open T-2B 7,334’7,341’5,909’5,916’7 2-3/8”1/17/20 Open T-6 7,481’7,506’6,045’6,068’25 2-3/8”12/15/15 Open T-7 7,546’7,571’6,105’6,128’25 2-3/8”12/15/15 Open T-10 7,830’7,885’6,371’6,394’55 2”12/11/05 Open 7,844’7,854’6,384’6,393’10 2-1/2”11/19/04 Open 7,844’7,854’6,384’6,393’10 2”5/5/05 Open T-17 8,198’8,228’6,718’6,747’30 2”5/4/05 Open 8,198’8,246’6,718’6,747’48 2-1/2”11/10&19/04 Open 8,218 8,246’6,737’6,764’28 2-1/2”5/2/05 Open 9-5/8” cement job:12-1/4” hole. 46bbls of 12.8# class G lead, and 31bbls of 15.8# class G tail. 20bbls cement mix back to surface 7” cement job:8-1/2” hole. 75bbls of 12.8# lead, and 14bbls of 15.8# class G tail. No losses noted. Volumetric ToC with 10% OH washout assumed = 350’ MD 3-1/2” cement job:6-1/8” hole. 155bbls of 12.0# Litecrete. ToC at 4460’ MD from 11/1/04 SCMT. STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,420 feet N/A feet true vertical 6,930 feet 8,238 (fill)feet Effective Depth measured 8,348 feet 3,616 feet true vertical 6,861 feet 2,836 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,661' MD 2,866' TVD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr; N/A 3,616' MD 2,836' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 575 Water-Bbl MD 73' 941' 0 Oil-Bbl measured true vertical Packer 3-1/2"8,416' 2,995' 6,926' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Deep Creek Field - HV Beluga / Tyonek GasN/A measured TVD Tubing Pressure 930 Happy Valley A-10 N/A FEE CIRI (C-061590) 3,850' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-186 50-231-20028-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-448 93 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 544 0 Representative Daily Average Production or Injection Data 73' 941' 3,850' 4,785' Conductor Surface Intermediate Production 10,540psi Casing Structural 13-3/8" 9-5/8" 7" Length 7,240psi 5,750psi Collapse 2,670psi 3,090psi 5,410psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 5,380psi 10,160psi 73' 924' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:08 am, Jan 19, 2021 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2021.01.18 08:46:48 -09'00' Taylor Wellman gls 2/1/21 SFD 1/26/2021RBDMS HEW 1/27/2021 DSR-1/19/21 Perforate N2 Rig Start Date End Date E-Line 12/17/20 12/18/21 PTW. Rig back up equipment. PT to 250 psi low and 3,500 psi high, Well is flowing. RIH w/ 2" x 10' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok from town to shoot from 5,456' to 5,466' w/Flow rate - 583.6K at 93 psi, Spotted and fired shot, After 5 min - 569.1K at 93.1 psi. 10 min - 538.9K at 93.1 psi and 15 min - 557K at 94.4. POOH. All shots fired and gun was dry. RIH w/GPT tool, 2"x6', HC, 6spf, 60 deg phase, switch sub, 2" x 7' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to shoot 6' gun first from 5,430' to 5,436' then pull up and shoot 5,414' to 5,421. Spotted and fired first gun picked up, spotted and fired second gun with last info. Fired with Well flowing 514.9K at 912.4 psi, 5 min - 538.6K at 93.1 psi, 10 min - 562.6 at 93.7 psi and. 15 min - 582K at 94.1 psi. Dropped to bottom and tagged at 8,231'. Started log GPT and logged up to 5,200'. POOH. All fired and gun was dry. Got a good log. Rig down equipment and turn well over to field. 12/17/2020 - Thursday Sign in at HVA. PTW and JSA. Spot equipment and rig up lubricator. PT t0 250 psi low and 3,500 psi high. Well had 310 psi on it shut in,. RIH with switches and four, 2" x 2' HC, 6 spf, 60 deg phase and tie into the log Matt sent us from town. Ran correlation log and send to town first shot was from 5,487-5,489', second shot - 5,460' to 5,462,. 3d shot was from 5,432' to 5,434' and 4th shot was from 5,417' to 5,419'. All shots fired. Shot with 305.6 psi, 5 min - 305.6 psi, 10 min - 306.5 psi and 15 min - 307.6 psi. All shots fired. FL - 5,750'. RIH w/ 2" x 20' HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to shoot from 5,478' to 5,498' with 321.1 psi. 5 min - 324.1 psi, 10 min - 323.7 psi and 15 min - 323.4 psi. POOH. all shots fired and gun was dry. Rig down lubricator and flow over night to see how it responds. TP - 325.4 psi 12/18/2020 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name HVA-10 50-231-22028-00-00 204-186 _____________________________________________________________________________________ Updated by DMA 01-07-21 SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 Last Completed: 11/19/2004 PTD: 204-186 API # 50-231-22028-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8' Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8" Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7" Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”" Liner 9.2 / L-80 / IBT-Mod 2.992 3,631’ 8,416' TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,661’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 2,502’ Chemical Injection Mandrel / Macco SFO-C1 2 3,616’ Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,626’ Locator Sub 4 3,660’ Muleshoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status BEL 50-51 5,414’ 5,421’ 4,232’ 4,238’ 7 12/18/20 Open 5,417’ 5,419’ 4,235’ 4,237’ 2 12/17/20 Open 5,430’ 5,436’ 4,246’ 4,251’ 6 12/18/20 Open 5,432’ 5,434’ 4,248’ 4,249’ 2 12/17/20 Open 5,456’ 5,466’ 4,268’ 4,276’ 10 12/18/20 Open 5,460’ 5,462’ 4,271’ 4,273’ 2 12/17/20 Open 5,478’ 5,498’ 4,286’ 4,303’ 20 12/17/20 Open 5,487’ 5,489’ 4,294’ 4,295’ 2 12/17/20 Open T-1 7,236’ 7,253’ 5,819’ 5,835’ 17 1/18/20 Open T-2B 7,334’ 7,341’ 5,909’ 5,916’ 7 1/17/20 Open T-6 7,481’ 7,506’ 6,045’ 6,068’ 25 12/15/15 Open T-7 7,546’ 7,571’ 6,105’ 6,128’ 25 12/15/15 Open T-10 7,830’ 7,885’ 6,371’ 6,394’ 25 12/11/05 Open 7,844’ 7,854’ 6,384’ 6,393’ 10 11/19/04 Open 7,844’ 7,854’ 6,384’ 6,393’ 10 5/5/05 Open T-17 8,198’ 8,228’ 6,718’ 6,747’ 30 5/4/05 Open 8,198’ 8,246’ 6,718’ 6,747’ 48 11/10&19/04 Open 8,218 8,246’ 6,737’ 6,764’ 28 5/2/05 Open OPEN HOLE / CEMENT DETAIL 9-5/8" Cmt w/ 77bbl of cement in 12-1/2” Hole 7” Cmt w/ 89bbl of cement in 12-1/4” Hole 3-1/2” Cmt w/ 155bbl of cement in 6-1/2” Hole Directional Data: Max Hole Angle = 49.2° @ 1,920’ KOP = 300’ Max Dog Legs = 4.2 Deg/100’ @ 547’ 5.1 Deg/100’ @ 1,037’ 3.5 Deg/100’ @ 4,077’ FISH DETAIL @ 8,231’ 12/18/20 6' gun - GPT tool, 2"x6', HC, 6spf BEL 50-51B 5,414’5,421’4,232’4,238’7 12/18/20 Open 5,417’5,419’4,235’4,237’2 12/17/20 Open 5,430’5,436’4,246’4,251’6 12/18/20 Open 5,432’5,434’4,248’4,249’2 12/17/20 Open 5,456’5,466’4,268’4,276’10 12/18/20 Open 5,460’5,462’4,271’4,273’2 12/17/20 Open 5,478’5,498’4,286’4,303’20 12/17/20 Open 5,487’5,489’4,294’4,295’2 12/17/20 Open () Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 01/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL HVA-10 (PTD 204-186) GPT 12/18/2020 Please include current contact information if different from above. PTD: 2041860 E-Set: 34574 Received by the AOGCC 01/14/2021 Abby Bell 01/14/2021 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 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 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 8,420'8,238' (fill) Casing Collapse Structural Conductor 2,670psi Surface 3,090psi Intermediate 5,410psi Production 10,540psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Jake Flora Operations Manager Contact Email: Contact Phone: 777-8442 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: November 1, 2020 3-1/2" 8,416' Perforation Depth MD (ft): 3,850' See Attached Schematic 4,785'6,926'3-1/2" 13-3/8" 9-5/8" 73' 7"3,850' 941' 5,380psi 5,750psi 73' 924' 2,995' 73' 941' 9.2# L-80 TVD Burst 3,661' 10,160psi MD 7,240psi Length Size CO 553A Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEE CIRI (C-061590) 204-186 50-231-20028-00-00 Happy Valley A-10 Deep Creek Field - HV Beluga / Tyonek Gas COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): See Attached Schematic jake.flora@hilcorp.com 6,930'8,348'6,861'1,501psi N/A Baker ZXP Packer; N/A 6,616' MD / 2,836' TVD; N/A Perforation Depth TVD (ft):Tubing Size: m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:52 am, Oct 20, 2020 320-448 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.10.19 14:27:13 -08'00' Taylor Wellman SFD 10/20/2020 DSR-10/20/2020 X 10-404 VTL 10/22/20 N2 Perforate Comm. 10/22/2020 dts 10/22/2020 RBDMS HEW 11/9/2020 Well Prognosis Well: HVA 10 Date: 10/15/2020 Well Name: HVA 10 API Number: 50-231-20028-00-00 Current Status: Online Gas Producer Leg: N/A Estimated Start Date: 11/01/20 Rig: E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-186 First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (C) Maximum Expected BHP: ~ 1924 psi @ 4232’ TVD (Based on a 0.45 psi/ft gradient) Max. Potential Surface Pressure: ~ 1501 psi Using Max BHP minus 0.1 psi/ft. gas gradient to surface). Well Summary / Objective HVA 10 has been on decline from the T6A for the past several years. The well is beginning to experience minor loading issues due to the low rate. This perf add will increase production rates in this well. Notes Regarding Wellbore Condition 3/1/2019 Slickline D&T; top of fill at 8272’ with 2.867” dummy gun Slickline Procedure: 1. Drift and tag fill, check for FL, run memory pressure/temp to TD. E-line & Nitrogen Procedure: 2. MIRU E-Line. PT Equipment. 3. RU N2, pressure up well with 1200 psi, likely less with open perfs below. 4. RIH and perforate the following interval: Sand MD Top MD Bottom TVD Top TVD Bottom Total Footage (MD) Expected Pressure (psig) BEL 50/51 ±5,413’ ±5,538’ ±4,232’ ±4,337’ 125’ 1924 a. Make GR/CCL correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. b. Spacing allowance is based on CO 553A. Proposed intervals are in the Beluga/Tyonek Gas Pool. c. Record initial and 5/10/15 minute tubing pressures after firing. d. Consult with RE/Geo between each perf interval: i. Anthony McConkey: RE - 529-6199 ii. Matthew Petrowsky: Geo – 814-421-6753 HVA 10 has been on decline from the T6A for the past several years. The well is beginning to experience minor loading issues due to the low rate. This perf add will increase production rates in this well. Well Prognosis Well: HVA 10 Date: 10/15/2020 5. CONTINGENT: If a zone is shown to make undesirable sand/water, set patch for shut-off a. MU 3-1/2” patch per vendor recommendation b. RIH and set over identified perf interval 6. Return well to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Standard Nitrogen SOP _____________________________________________________________________________________ Updated by DMA 01-20-20 SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 Last Completed: 11/19/2004 PTD: 204-186 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8' Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8" Surface 40 /L-80 / BTC-Mod 8.835 Surf 941 7" Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”" Liner 9.2 / L-80 / IBT-Mod 2.992 3,631’ 8,416' TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / IBT-Mod 2.992 Surf 3,661’ NOTE: Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 2,502’ Chemical Injection Mandrel / Macco SFO-C1 2 3,616’ Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,626’ Locator Sub 4 3,660’ Muleshoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status T-1 7,236’ 7,253’ 5,819’ 5,835’ 17 1/18/20 Open T-2B 7,334’ 7,341’ 5,909’ 5,916’ 7 1/17/20 Open T-6 7,481’ 7,506’ 6,045’ 6,068’ 25 12/15/15 Open T-7 7,546’ 7,571’ 6,105’ 6,128’ 25 12/15/15 Open T-10 7,830’ 7,885’ 6,371’ 6,394’ 25 12/11/05 Open 7,844’ 7,854’ 6,384’ 6,393’ 10 11/19/04 Open 7,844’ 7,854’ 6,384’ 6,393’ 10 5/5/05 Open T-17 8,198’ 8,228’ 6,718’ 6,747’ 30 5/4/05 Open 8,198’ 8,246’ 6,718’ 6,747’ 48 11/10&19/04 Open 8,218 8,246’ 6,737’ 6,764’ 28 5/2/05 Open OPEN HOLE / CEMENT DETAIL 9-5/8" Cmt w/ 77bbl of cement in 12-1/2” Hole 7” Cmt w/ 89bbl of cement in 12-1/4” Hole 3-1/2” Cmt w/ 155bbl of cement in 6-1/2” Hole Directional Data: Max Hole Angle = 49.2° @ 1,920’ KOP = 300’ Max Dog Legs = 4.2 Deg/100’ @ 547’ 5.1 Deg/100’ @ 1,037’ 3.5 Deg/100’ @ 4,077’ _____________________________________________________________________________________ Updated by JMF 10-16-20 PROPOSED SCHEMATIC Deep Creek (Happy Valley) Well: HVA-10 Last Completed: 11/19/2004 PTD: 204-186 TD = 8,420’(MD) /6,930’(TVD) RKB: MSL = 16.4’ 7” 2 13-3/8” 9-5/8” 1 TOF @ 8,255’ Tagged 3/22/05 w/ 2” DDBailer T-TT 10 3-1/2” PBTD = 8,348’(MD)/ 6,861’ (TVD) T-TT 17 3 4 T-7 T-TT 6 T-TT 2B T-TT 1 BEL 50-51 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8'Conductor 72 / N-80 / BTC-Mod 12.347 Surf 73' 9-5/8"Surface 40 /L-80 /BTC-Mod 8.835 Surf 941 7"Intermediate 26 / L-80 / BTC-Mod 6.276 Surf 3,850’ 3-1/2”"Liner 9.2 /L-80 / IBT-Mod 2.992 3,631’8,416' TUBING DETAIL 3-1/2"Tubing 9.2 /L-80 / IBT-Mod 2.992 Surf 3,661’ NOTE:Annulus Loaded with 3% KCl Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 2,502’ Chemical Injection Mandrel / Macco SFO-C1 2 3,616’Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,626’Locator Sub 4 3,660’Muleshoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD)Btm (TVD) FT Date Status BEL 50-51 ~5,413’~5,538’~4,232’~4,337’125 NA Planned T-1 7,236’7,253’5,819’5,835’17 1/18/20 Open T-2B 7,334’ 7,341’5,909’ 5,916’7 1/17/20 Open T-6 7,481’7,506’6,045’6,068’25 12/15/15 Open T-7 7,546’7,571’6,105’6,128’25 12/15/15 Open T-10 7,830’ 7,885’ 6,371’ 6,394’25 12/11/05 Open 7,844’7,854’6,384’ 6,393’10 11/19/04 Open 7,844’7,854’6,384’ 6,393’10 5/5/05 Open T-17 8,198’ 8,228’ 6,718’ 6,747’30 5/4/05 Open 8,198’ 8,246’ 6,718’ 6,747’ 48 11/10&19/04 Open 8,218 8,246’ 6,737’ 6,764’28 5/2/05 Open OPEN HOLE / CEMENT DETAIL 9-5/8"Cmt w/77bbl of cement in 12-1/2” Hole 7” Cmt w/ 89bbl of cement in 12-1/4” Hole 3-1/2”Cmt w/ 155bbl of cement in 6-1/2” Hole Directional Data: Max Hole Angle = 49.2° @ 1,920’ KOP = 300’ Max Dog Legs = 4.2 Deg/100’ @ 547’ 5.1 Deg/100’ @ 1,037’ 3.5 Deg/100’ @ 4,077’ STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 2 4 2020 AOGrC: 1. Operations Abandon LJ Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:--ta==R�- 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 204-186 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-231-20028-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE CIRI (C-061590) Happy Valley A-10 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Deep Creek Field - HV Beluga / Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 8,420 feet Plugs measured N/A feel true vertical 6,930 feet Junk measured 8,238 (fill) feet Effective Depth measured 8,348 feet Packer measured 3,616 feet true vertical 6,861 feet true vertical 2,836 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' 5,380 psi 2,670 psi Surface 941' 9-5/8" 941' 924' 5,750 psi 3,090 psi Intermediate 3,850' 7" 3,850' 2,995' 7,240 psi 5,410 psi Production 4,785' 3-1/2" 8,416' 6,926' 10,160 psi 10,540 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 3,661' MD 2,866' ND Packers and SSSV (type, measured and true ver&al depth) Baker ZXP Pkr; N/A 3,616' MD 2,836' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 614 0 0 93 Subsequent to operation: 0 613 0 0 96 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-580 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.00m Authorized Signature Date: L 3 441 Z UZ-O Contact Phone: 777-8420 Form 10-404 Revised 4/2017k Z y, , J _d/7'0W Submit Original Only / �BDMS �JAN12 7 2020 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date HVA -10 E -Line 1 50-231-22028-00 1 204-186 1/17/20 1/18/20 Daily Operations: - 01/17/2020 - Friday PJSM and PTW. Rig up Halliburton E -line unit on well. HVA -10 is flowing-624MCF with 92psi tubing pressure. Halliburton crane was non-operable and thawed out with a frost fighter heater. R/U BOPE's and lubricator w/ GPT tool Pressure test to 250 psi low and 2,500 psi high. TEST GOOD RIH with QPC and CPF (GPT) tools to 8,224' and set down. No fluid was observed on GPT run. Correlated depth with Matt Petrowsky. POOH M/U and RIH with Gamma, CCL, and 2-3/8" x 7' GeoDynamics Razor 6spf TT HCS Scallop SemiExp. Correlate depth with Matt Petrowsky and perforated T- 2B sands from 7,334' to 7,341'. Tubing pressure before shots 96psi then a 2 psi gain to 98psi after 35 minutes. POOH. R/D Halliburton E -line and secure well for the night. Leave equipment on location to continue perforating tomorrow. 01/18/2020 -Saturday PJSM and PTW. Rig up Halliburton E -line unit. Found galled threads on the bottom GPT connection, Halliburton returned to Sterling to pick-up a new GPT tool. S/D waiting on replacement GPT tool. M/U and RIH with Gamma, CCL, and 2-3/8" x 17' GeoDynamics Razor 6spf TT HCS Scallop SemiExp. Correlate depth with Matthew Pertowsky and perforated T-1 sands from 7,236' to 7,253'. Tubing pressure before shots 96psi, no pressure increase seen in the first 15 minutes. POOH. All shots fired. R/D Halliburton E -line and return turn well back over to production. Deep Creek (Happy Valley) SCHEMATIC Well: HVA -10 Last Completed: 11/19/2004 Hilcory Alnska, LLC PTD: 204-186 RKB: MSL =16.4' 13-3/8" TOF @ 8,755 Tagged 3M/05'- w/ /22/05w/ 2" DDBailer 3-1/2" TD= 8,42Y(MD) /6,930'(TVD) PBTD=8,348'(MD)/6,861' (ND) CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 13-3/8' Conductor 72 / N-80/ BTC -Mod 12.347 Surf 73' 9-5/8" Surface 40/L-80/BTC-Mod 8.835 Surf 941 7" Intermediate 26 / L-80/ BTC -Mod 6.276 Surf 3,8W 3-1/2"" Liner 9.2/L -80/187 -Mod 1 2.992 3,631' 1 8,416' TUBING DETAIL 3-1/2" 1 Tubing 9.2/L-80/IBT-Mod I 2.992 Surf T 3,661' NOTE: Annulus Loaded with 3% KCI Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 2,502' Chemical Injection Mandrel / Macco SFO -C3 2 3,616' Baker ZXP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,626' Locator Sub 4 3,660' Muleshoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) (TVD)M12/11/05 Status T-1 7,236' 7,253' 5,819' 5,835' Open T-2B 7,334' 7,341' 5,909' 5,916' Open T-6 7,481' 7,506' 6,045' 6,068'5 Open T-7 7,546' 7,571' 6,105' 6,128' Open 7,830' 7,885' 6,371' 6,394'5 Open T-10 7,844' 7,854' 6,384' 6,393' 10 11/19/04 Open 7,844' 7,854' 6,384' 6,393' 30 5/5/05 Open 8,198' 8,228' 6,718' 6,747' 30 5/4/05 Open T-17 8,198' 1 8,246' 1 6,718' 6,747' 1 48 1 11/10&19/04 Open 8,218 1 8,246' 1 6,737' 6,764' 1 28 1 5/2/05 open OPEN HOLE / CEMENT DETAIL 9-5/8" Cmt w/ 77bbl of cement in 12-1/2" Hole 7" Dint w/ 89bb1 of cement in 12-1/4" Hole 3-1/2" I Cmt w/ 155bb1 of cement in 6-1/2" Hole Directional Data: Max Hole Angle = 49.2° @ 1,920' KOP = 300' Max Dog Legs = 4.2 Deg/100' @ 547' 5.1 Deg/100' @ 1,037' 3.5 Deg/100' @ 4,077' Updated by DMA 03-20-20 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Deep Creek Field, HV Beluga/Tyonek Gas Pool, Happy Valley A-10 Permit to Drill Number: 204-186 Sundry Number: 319-580 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.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, ssie L. Cbmielowski Commissioner DATED this 20 day of December, 2019. 3BDMS W -"JAN 9 2 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 nnc 25 Zan �d 6 DEC 18 2019 &--s//'++[ t/za/l 9 !' OGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[] Suspend Q Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N221 2. Operator Name: Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development PI- Stratigraphic6. ❑ Service El 204-186 3. Address: 3800 Centerpoint Drive, Suite 1400 API Number: Anchorage, Alaska 99503 50-231-20028-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553/1- Will planned perforations require a spacing exception? Yes ElNo❑ L,t ' t% Happy Valley A-10 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE CIRI (C-061590) Deep Creek Field - HV Beluga / Tyonek Gas it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,420' 6,930' 8,348' 6,861' -610 N/A 8,238- (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' 5,380psi 2,670psi Surface 941' 9-5/8" 941' 924' 5,750psi 3,090psi Intermediate 3,850' 7" 3,850' 2,995' 7,240psi 5,410psi Production 4,785' 3-1/2" 8,416' 1 6,926' 10,160psi 1 10,540psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / L-80 3,661' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP Packer and N/A 3,616'(MD) / 2,836'(TVD) and N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q "Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:Bemn bur 241h, 26 p OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Christina Twogood Authorized Name: Bo York 777-8345 Contach Email: ctwogood@hilcorp.com Authorized Title: Operations Manager Contact Phone: 777-8443 ,1 Authorized Signatu Date: D LL 2-6 It 9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -58 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Q Location Clearance C1 Other: p �ry�+ 3BDMS *,/.iAN 0 2 2920 Post Initial Injection MIT Rep'tl? Yes ❑ No ❑ Spacing Exception Required? Yes No Subsequent Form Required: I o— LloLf APPROVED BY Approved by: /- , COMMISSIONER THE COMMISSION Date: l 1 Z %%d 11 C Farm and / For 0-403 Revised 17/2015 Approved applicatin id s the date of approval. Attachments in Duplicate H FGlrnu Alaska, LL Well Prognosis Well: HVA -10 Date:12/12/2019 Well Name: HVA -10 API Number: 50-231-20028-00-00 Current Status: Gas Producer S3u to Leg: N/A Estimated Start Date: n emhy�o'-9 Rig: E -Line Reg. Approval Req'd: 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number:-- 204 186 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Max. Expected BHP: Max. Potential Surface Pressure: Brief Well Summary 1,200 psi @ 5,918' TVD " 610 psi (Based on depleted gradient) (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) HVA -10 was drilled in October 2004 by Unocal targeting Upper Tyonek in the Deep Creek Unit. It was initially perforated in the T-17 and T-10 sand which ended up being the best well in the field. T-17 sand flowed at 1,187 psi post-perf. T-17 & T-10 flowed at 1,394 psi post -pert. In December 2015, the T6 & 6A sands were perforated. The purpose of this sundry is to add perforations in the Tyonek T-1 and T-213 sands. Notes Regarding Wellbore Condition • Last tag (tagged sand) at 8,238' KB w/ 2.125" tool OD during Flowing PT Survey on 9/8/2018 • Drift and Tag Prior to Perforating Safety / • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people �C could enter. • Consider tank placement based on wind direction and current weather forecast (venting nitrogen during this job). • Ensure all crews are aware of stop job authority. E -Line Procedure: 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RQ_UlLrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. RU perf guns. 0 Hilcarp Alaska. LL 5. RIH and perforate the following intervals: Well Prognosis Well: HVA -10 Date: 12/12/2019 Zone Sands Top (MD) Btm (MD) Top( Btm (ND) Ft Tyonek T-1 +7,227' +7,253' +5,811' +5,835' 25 Tyonek T-26 +7,334' +7,343' +5,909' ±5,918' 25 a. Well may be shot flowing. b. Proposed perfs also shown on the proposed schematic in red font. c. Final perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer and Geologist for confirmation. e. Use Gamma/CCL to correlate. f. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. g. All perforations in the table above are located in the Tyonek Gas Pool based on Conservation Order No. 55311, 6. POOH. 7. RD E -Line. 8. Turn well over to production. (Test SSV with -in 5 days of stable production on well —notify AOGCC 24 hrs before testing.) E -Line Procedure (Contingency) 1. If any zone produces sand and/or water or needs isolated: 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,500 psi High. 3. RIH and set 3-1/2" Casing Patch or set 3-1/2" CIBP above the zone and dump 35' of cement on top of the plug. Attachments 1. Actual Schematic 2. Proposed Schematic 3. Standard Well Procedure—N2 Operations ff Hilmro Alaska, LLC 13-3/8" 7„ RKB: MSL=16.4' roF@Sass' Tagged 3/22/05 W/ Y' DDBaHer 3-1/2" 2 3 TO= 8,42(Y(MD) /6,930'(ND) PBTD= 8,348'(W)/ 6,861' (TVD) SCHEMATIC CASING Deep Creek (Happy Valley) Well: HVA -10 Last Completed: 11/19/2004 PTD: 204-186 Size Type Wt/Grade/Conn ID Top Btm 13-3/8' Conductor 72/N-80/BTC-Mad 12.347 Surf 73' 9-5/8" Surface 40A-80/BTC-Mod 8.835 Surf 941 7" Intermediate 26/L-80/BTC-Mod 6.276 Surf 3,850' 3-1/2"" Liner 9.2/L-80/IBT-Mod 2.992 3,631' 8,416' TUBING DETAIL 3-1/2"Tubing 9.2/L-80/I8T-Mod 2.992 Surf 3,661' NOTE: Annulus Loaded with 3% KCI Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 2,502' Chemical Injection Mandrel / Macco SFO -CS 2 3,616' Baker 2xP Packer, Flexlock Liner Hanger & 80-40 Sealbore 3 3,626' Locator Sub 4 3,660' Muleshoe PERFORATION nFTAII Sands Top (MD) Btm (MD) Top (TVD) atm ( FT Date Status T-6 7,481' 7,506' 6,045' 6,068' 25 12/15/15 Open T-7 7,546' 7,571' 6,105' 6,128' 25 12/15/15 Open 7,830' 7,885' 6,371' 6,394' 25 12/11/05 Open T-10 7,844' 7,854' 6,384' 6,393' 10 11/19/04 Open 7,844' 7,854' 6,384' 6,393' 10 5/5/05 Open 8,198' 8,228' 6,718' 6,747 30 5/4/05 Open T-17 8,198' 8,246' 6,718' 6,747' 48 11/10&19/04 Open 8,218 8,246' 6,737' 1 6,764' 1 28 5/2/05 1 Open OPEN HOLE / CEMENT DETAIL 9-5/8" 1 Cmt w/ 771bb1 of cement in 12-1/2" Hole 7" Cmt w/ 89bbl of cement in 12-1/4" Hole 5-11Z I Cmt w/ 155bbi of cement in 6-1/2" Hole Directional Data: Max Hole Angle = 49.2° @ 1,920' KOP = 300' Max Dog Legs = 4.2 Deg/100' @ 547' 5.1 Deg/100' @ 1,037' 3.5 Deg/100' @ 4,077' Updated by DMA 03-12-16 Deep Creek (Happy Valley) PROPOSED SCHEMATIC Well: HVA -10 Last Completed: 11/19/2004 fiilcurp .4Fn,Ln, LLC PTD: 204-186 13-3/8" 7„ RKB: MSL =16.4' 1 T0F @ 8,255' Tagged3/22/05 'o 2" DOM er - 3-ur 2 3 TD = 8,42U(MD) /6,93U'(TVD) PBTD = 8,348'(MD)/ 6,861' (TVD) CASING DETAIL Size Type Wt/Grade/Conn ID TopE Chemical Injection Mandrel/ Macco SFO -C3 13-3/8' Conductor 72/N-80/BTC-Mod 12.347 Surf Locator Sub 9-5/8" Surface 40 /L-80/BTC-Mod 8.835 Surf 7,334' 7" Intermediate 26/L-80/BTC-Mod 6.276 Surf Proposed 3-1/2"" Liner 9.2 / L-80 / IBT-Mod 2.992 :3,631 25 TUBING DETAIL 3-1/2" L Tubing 9.2/L-80/IBT-Mod 2.992 Surf 3,661' NOTE: Annulus Loaded with 3% KCI Brine Plus Corrosion Inhibitor JFWFLRY DFTAII No Depth Item 1 2,502' Chemical Injection Mandrel/ Macco SFO -C3 2 3,616' Baker 2XP Packer, Flexlock Liner Hanger&80-40 Sea [bore 3 3,626' Locator Sub 4 3,660' Muleshoe PERFORATION DFTAII Sands Top (MD) Btm (MD) Top (TVD) (TVD) FT Date Status T-1 7,227' 7,253' 5,811' 5,835' 26 TBD Proposed T-2B 7,334' 7,34 5,969' 5,918' 9 TBD Proposed T-6 7,481' 7,506' 6,045' 6,068' 25 12/15/15 Open T-7 7,546' 7,571' 6,105' 6,128' 25 12/15/15 Open 7,830' 7,885' 6,371' 6,394' 25 12/11/05 Open T-10 7,844' 7,854' 6,384' 6,393' 10 11)19/04 Open 7,844' 7,854' 6,384' 6,393' 10 5/5/05 Open 8,198' 8,228' 6,718' 6,747' 30 5/4/05 Open T-17 8,198' 1 8,246' 6,718' 6,747'48 1 11/30&19/04 1 Open 8,218 8,246' 6,737' 6,764' 28 1 5/2/05 1 Open OPEN HOLE / CEMENT DETAIL 9-5/8" Cmt w/ 77bbi of cement in 12-1/2" Hole 7" Cmt w/ 89bbl of cement in 12-1/4" Hole 3-1/2" 1 Cmt w/ 155bbl of cement in 6-1/2" Hole Directional Data: Max Hole Angle = 49.2° @ 1,920' KOP = 300' Max Dog Legs = 4.2 Deg/100' @ 547' 5.1 Deg/100' @ 1,037' 3.5 Deg/100' @ 4,077' Updated by CMT 12-12-2019 STANDARD WELL PROCEDURE Ililonrp Alaska, LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FI NAL v1 Page 1 of 1 Debra Oudean GeoTech A4f l4LLC DATE 3/28/2019 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA PDF Document TRANSMITTAL 11/13/201 8 9:46 APA LAS File 1,134 KB 11/13/2018 9:46 AM LAS Fite 1,072 KB 11/13,120189:46AM Happy 1, 156 KB Valley A-10 (PTD 11/13/20169:46AM TIFF File 204-186) 11/13/20189:46AM LAS Fite CD: �i HVA -10 PPROF OBSEP18 HVA-10_PPROF OBSEP78_7430 HVA-10_PPROF_08SEP18_7520 HVA-10_PPROF OBSEP18_78W HVA-10_PPROF OBSEPI8_8111 HVA-10_PPROF 03SEP18_img j HVA-10_PPROF 08SEP18_MAIN PASS 2041&b 30 53 1 RECEIVED APR 0 1 2019 AOGCC 11/13/20189:46AM PDF Document 2,732 KB 11/13/201 8 9:46 APA LAS File 1,134 KB 11/13/2018 9:46 AM LAS Fite 1,072 KB 11/13,120189:46AM LAS File 1, 156 KB 11/13.12018 9:46 AM LAS Fite 1,236 KB 11/13/20169:46AM TIFF File 3,587 KB 11/13/20189:46AM LAS Fite 5,022 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 STATE OF ALASKA • • ALL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations H Fracture Stimulate A Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing❑ Change Approved Program Plug for Redrill ❑ 3rforate New Pool H Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 204-186 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-231-20028-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE CIRI(C-061590) Happy Valley A-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Deep Creek Field-HV Beluga/Tyonek Gas 11.Present Well Condition Summary: Total Depth measured 8,420 feet Plugs measured N/A feet 1 true vertical 6,930 feet Junk measured 8,255(fill) feet 7 VED Effective Depth measured 8,348 feet Packer measured 3,616 feet JAN 1 3 2016 true vertical 6,861 feet true vertical 2,836 feet AOGGL Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' 5,380 psi 2,670 psi Surface 941' 9-5/8" 941' 924' 5,750 psi 3,090 psi Intermediate 3,850' 7" 3,850' 2,995' 7,240 psi 5,410 psi Production 4,785' 3-1/2" 8,416' 6,926' 10,160 psi 10,540 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic S ED FEB Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 3,661'MD 2,866'TVD Packers and SSSV(type,measured and true vertical depth) Baker ZXP Pkr;N/A 3,616'MD 2,836'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,110 0 0 103 Subsequent to operation: 0 1,740 0 0 120 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory H Development❑ Service ❑ Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑� WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR H WINJ ❑ WAG ❑ 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: 315-722 Contact Taylor Nasse-777-8354 Email tnasse@hilcorp corn Printed Name Chad Helgeson Title Operations Manager � Signature L%7 / l Phone 907-777-8405 Date 1131)6, RBDMS L1.- JAN 1 9 2016 Form 10-404 Revised 5/2015 2Z 7.---27-/4 Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date HVA-10 E-Line 50-231-22028-00 204-186 12/15/15 12/15/15 Daily Operations: 12/15/2015-Tuesday PTW and JSA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high. Arm gun. RIH w/2- 3/8" x 25' HC Connex, 5 spf, 60 deg phase and tie into SLB SCMT log dated 1-Nov-2004. Run correlation log and send to town. Get ok to perf the T-7 sand from 7,546'to 7,571'.,Spot gun with tubing pressure at 373.2 psi. Fired gun and pressure went to 376.5 psi and after 5 min it still was the same. POOH. All shots fired and gun was dry. RIH w/2-3/8" x 25' HC Connex, 5 spf, 60 deg phase and tie into SLB SCMT log dated 1-Nov-2004. Run correlation log and send to town. Get ok to perf the T-6 sand from 7,481'to 7,506'. Spot gun with tubing pressure at 390 psi. Fired gun and pressure started building right away. After 5 min pressure was 465 psi. POOH. All shots fired and gun was dry. Pressure was 583 psi when out of hole. Gained 196 psi in 30 min. All shots fired and gun looked dry.TP is 617 psi. Rig down lubricator and turn well over to field. HO ! Deep Creek (Happy Valley) sm Well: HVA-10 SCHEMATIC Last Completed: 11/19/2004 Hikorp Alaska,LLC PTD: 204-186 CASING DETAIL RKB:MSL=16.4' Size Type Wt/Grade/Conn ID Top Btm 13-3/8"J l 13-3/8' Conductor 72/N-80/BTCMod 12.347 Surf 73' 9-5/8" Surface 40/L-80/BTC-Mod 8.835 Surf 941 7" Intermediate 26/L-80/BTC-Mod 6.276 Surf 3,850' 3-1/2"" Liner 9.2/L-80/IBT-Mod 2.992 3,631' 8,416' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT-Mod 2.992 Surf 3,661' 9-5/8' NOTE:Annulus Loaded with 3%KCI Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 1 2,502' Chemical Injection Mandrel/Macco SFO-C1 2 3,616' Baker ZXP Packer,Flexlock Liner Hanger&80-40 Sealbore 3 3,626' Locator Sub 4 3,660' Muleshoe PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status X X 2 T-6 7,481' 7,506' 6,045' 6,068' 25 12/15/15 Open ✓ 7». •3 T-7 7,546' 7,571' 6,105' 6,128' 25 12/15/15 Open 4 7,830' 7,885' 6,371' 6,394' 25 12/11/05 Open T-10 7,844' 7,854' 6,384' 6,393' 10 11/19/04 Open 7,844' 7,854' 6,384' 6,393' 10 5/5/05 Open 8,198' 8,228' 6,718' 6,747' 30 5/4/05 Open 1-17 8,198' 8,246' 6,718' 6,747' 48 11/10&19/04 Open 8,218 8,246' 6,737' 6,764' 28 5/2/05 Open OPEN HOLE/CEMENT DETAIL 9-5/8" Cmt w/77bb1 of cement in 12-1/2"Hole 7" Cmt w/89bbl of cement in 12-1/4"Hole 3-1/2" Cmt w/155bb1 of cement in 6-1/2"Hole Directional Data: Max Hole Angle=49.2° @ 1,920' KOP=300' Max Dog Legs= 4.2 Deg/100' @ 547' 5.1 Deg/100' @ 1,037' 3.5 Deg/100' @ 4,077' =T-6 =T--7 T-10 TOF @8,255' Tagged 3/22/05 =T-17 w/2"DDBailer 3-1/2"a • TD=8,420'(MD)/6,930'(TVD) PBTD=8,348'(MD)/6,861'(TVD) Updated by DMA 01-12-16 OF 7,4 • 111) • 4 w\�\ s THE STATE Alaska Oil and Gas ofAfAsKA Conservation Commission =— 333 West Seventh Avenue ITh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax:Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 v Anchorage, AK 99503 Re: Deep Creek Field, Tyonek Gas Pool, HV A-10 Sundry Number: 315-722 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissoiner DATED this day of December, 2015 Encl. RBDMS ( EC 112015 �Q4 �ti RECEIVED STATE OF ALASKA NOV 2 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A (-..1 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate El ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC - Exploratory ❑ Development ❑✓ - 204-186 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-231-20028-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553 ' Happy Valley A-10 Will planned perforations require a spacing exception? Yes ❑ No 0 - 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE CIRI(C-061590) ' Deep Creek Field-HV Beluga/Tyonek Gas - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,420' - 6,930' • 8,348' ' 6,861' ' 2,371 psi N/A 8,255(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' 5,380psi 2,670psi Surface 941' 9-5/8" 941' 924' 5,750psi 3,090psi Intermediate 3,850' 7" 3,850' 2,995' 7,240psi 5,410psi Production 4,785' 3-1/2" 8,416' 6,926' 10,160psi 10,540psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80 3,661' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker ZXP Packer and N/A 3,616'(MD)/2,836'(TVD)and N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ - Service ❑ 14. Estimated Date for 15.Well Status after proposed work: December 9,2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E. WAG LI GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasse@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature /—//7// Phone 907-777-8405 Date 1/725/15— COMMISSION l ZS/1r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315- -122 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ ■`B MS UEC 1 1 2015 Spacing Exception Required? Yes Li No © I Subsequent Form Required: /o— 0 `J'lL J / Approved by: % aAPPROVED BY COMMISSIONERa THE COMMISSION Date: // � ) Z/ /5 ,/ /2.2—•1c ® Submit Form and Form 10-403 Revised /2015 r v i s slid for 12 months from the date of approval. � A chm nts i Duplicate • • Well Prognosis Well: HVA-10 .%Ia.k.i,I.i. Date: 11/25/2015 Well Name: HVA-10 API Number: 50-231-20028-00 Current Status: Producing Leg: N/A Estimated Start Date: December 9th, 2015 Rig: E-Line Reg.Approval Req'd: 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-186 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current BHP: —438 psi @ 6,625' TVD (Downhole PBU 8/15/15) Maximum Possible BHP: —2,635 psi @ 6,128' TVD (Assumed 0.43 psi/ft gradient) Max. Predicted Surface Pressure: —2,371 psi (0.10 psi/ft gas gradient) Brief Well Summary HVA-10 was drilled in October 2004 by Unocal targeting Upper Tyonek in the Deep Creek Unit. It was initially perforated in the T-17 and T-10 sand which ended up being the best well in the field. - The purpose of this sundry is to add additional perforations in the Tyonek sands. Notes Regarding Wellbore Condition • Well is currently flowing 1.1 MMS-CFD at 113 psig. • Slickline tag and make gauge ring run prior to starting work. • Shut in well 2 hours before perforating. E-line Procedure: 1. MIRU e-line and PT lubricator to 3,000 psi Hi 250 Low. 2. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Tyonek sands with GeoDynamics 2-3/8" 5 SPF 60 deg phased perf guns. Depths are from the Schlumberger Cement Bond Log dated November 1st, 2004. Send the correlation pass to Taylor Nasse and Dave Buthman for confirmation. Zone Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft SPF Date Status Tyonek T-6 7,481' . 7,506' 6,045' 6,068' 25 5 TBD Proposed T-7 7,546' • 7,571' 6,105' 6,128' 25 5 TBD Proposed 4. POOH. 5. Flow well through test separator and record water and gas rates. Note: If any of the sands are not commercial,then the zone will be plugged back with a bridge plug or casing patch. • • Well Prognosis Well: HVA-10 Hikora Alaska,LLQ Date: 11/25/2015 6. RD e-line. 7. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • tit . . Deep Creek (Happy Valley) Well: HVA-10 SCHEMATIC Last Completed: 11/19/2004 Hilcorp Alaska,LLC PTD: 204-186 CASING DETAIL RKB:MSL=16.4' Size Type Wt/Grade/Conn ID Top Btm 13-3/8"i I 13-3/8' Conductor 72/N-80/BTC-Mod 12.347 Surf 73' 9-5/8" Surface 40/L-80/BTC-Mod 8.835 Surf 941' 7" Intermediate 26/L-80/BTC-Mod 6.276 Surf 3,850' 3-1/2"" Liner 9.2/L-80/IBT-Mod 2.992 3,631' 8,416' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT-Mod 2.992 Surf 3,661' 9'5/8" NOTE:Annulus Loaded with 3%KCI Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item 1 1 2,502' Chemical Injection Mandrel/Macco SFO-C1 2 3,616' Baker ZXP Packer,Flexlock Liner Hanger&80-40 Sealbore 3 3,626' Locator Sub 4 3,660' Muleshoe PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status Z 2 7,830' 7,885' 6,371' 6,394' 25 12/11/05 Open 7» •3 T-10 7,844' 7,854' 6,384' 6,393' 10 11/19/04 Open 4 7,844' 7,854' 6,384' 6,393' 10 5/5/05 Open 8,198' 8,228' 6,718' 6,747' 30 5/4/05 Open T-17 8,198' 8,246' 6,718' 6,747' 48 11/10&19/04 Open 1 8,218 8,246' 6,737' 6,764' 28 5/2/05 Open OPEN HOLE/CEMENT DETAIL 9-5/8" Cmt w/77bb1 of cement in 12-1/2"Hole 7" Cmt w/89bb1 of cement in 12-1/4"Hole 3-1/2" Cmt w/155bb1 of cement in 6-1/2"Hole Directional Data: Max Hole Angle=49.2° @ 1,920' KOP=300' Max Dog Legs= 4.2 Deg/100' @ 547' 5.1 Deg/100' @ 1,037' 3.5 Deg/100' @ 4,077' =T-10 TOF@8,255' - Tagged 3/22/05 =T-17 w/Y'DDBailer 3-1/2"a 6 TD=8,420'(MD)/6,930'(1VD) PBTD=8,348'(MD)/6,861'(TVD) Created By:TDF 5/12/2014 . H • Deep Creek (Happy Valley) Well: HVA-10 PROPOSED Last Completed: 11/19/2004 Hilcorp Alaska,LLC PTD: 204-186 CASING DETAIL RKB:MSL=16.4' Size Type Wt/Grade/Conn ID Top Btm 13-3/8", l 13-3/8' Conductor 72/N-80/BTC-Mod 12.347 Surf 73' 9-5/8" Surface 40/L-80/BTC Mod 8.835 Surf 941 7" Intermediate 26/L-80/BTC-Mod 6.276 Surf 3,850' 3-1/2"" Liner 9.2/L-80/IBT-Mod 2.992 3,631' 8,416' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT-Mod 2.992 Surf 3,661' 9-5/8'a NOTE:Annulus Loaded wit! v.KCI Brine Plus Corrosion Inhibitor JEWELRY DETAIL No Depth Item .1m,"--‘11 1 2,502' Chemical Injection Mandrel/Macco SFO-C1 2 3,616' Baker ZXP Packer,Flexlock Liner Hanger&80-40 Sealbore 3 3,626' Locator Sub 4 3,660' Muleshoe PERFORATION DETAIL Btm Sands Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status Z 2 T-6 ±7,481' ±7,506' ±6,045' ±6,068' 25 Future Proposed 7„ •3 T-7 ±7,546' ±7,571' ±6,105' ±6,128' 25 Future Proposed Tr • 4 7,830' 7,885' 6,371' 6,394' 25 12/11/05 Open T-10 7,844' 7,854' 6,384' 6,393' 10 i 11/19/04 Open 7,844' 7,854' 6,384' 6,393' 10 5/5/05 Open 8,198' _ 8,228' 6,718' 6,747' 30 i 5/4/05 Open T-17 8,198' _ 8,246' 6,718' 6,747' 48 i 11/10&19/04 Open 8,218 8,246' 6,737' 6,764' 28 5/2/05 Open OPEN HOLE/CEMENT DETAIL 9-5/8" Cmt w/77bb1 of cement in 12-1/2"Hole 7" Cmt w/89bb1 of cement in 12-1/4"Hole 3-1/2" Cmt w/155bbl of cement in 6-1/2"Hole Directional Data: Max Hole Angle=49.2° @ 1,920' KOP=300' Max Dog Legs= 4.2 Deg/100' @ 547' 5.1 Deg/100' @ 1,037' 3.5 Deg/100' @ 4,077' T-6 r_7 T-10 TOE @ 8,255' Tagged 3/22/05 T-17 w/2"DDBailer 3-1/2"a TD=8,420'(MD)/6,930'(TVD) PBTD=8,348'(MD)/6,861'(TVD) Created By:TWN 11/24/2015 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may bescanned during a special rescan activity or are viewable by direct inspection of the file. ~ ð.. ~ - 1 ~ Co Well History File Identifier Organizing (done) D Two-sided 11111111111" 111111 D Rescan Needed 111111111111 "" III RES CAN yøiolor Items: ~GreYSCale Items: D Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, Norrype: Date 1;;../' c¡ / Q ~ i J OVERSIZED (Non-Scannable) ~9S of various kinds: D Other:: D Other: NOTES: BY: ~ 151 mf '" II 111111111 "III Project Proofing BY: ~ Date: J~/IC¡ It) ~ I I 3 90 Date: " 151 ocf BY: + '7 = TOTAL PAGES I () '7 (Count does not include cover sheet) 151 Scanning Preparation 11111111111111" III Production Scanning Stage 1 Page Count from Scanned File: I 0 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date: I d-/¡q/O{¡; If NO in stage 1, page(s) discrepancies were found: YES NO 151 m p NO BY: Stage 1 BY: Maria Date: 151 11111111111I11 1111I Scanning is complete at this point unless rescanning is required. ReScanned "' 1111111111' "'II BY: Maria Date: 151 Comments about this file: Quality Checked III 111/1111I111111I 10/6/2005 Well History File Cover Page.doc • • ~~_ ~,Y ~- ~. MICROFILMED 03!01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.~c /q D~c. DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041860 Well Name/No. HAPPY VALLEY A-10 Operator UNION OIL CO OF CALIFORNIA MD 8420..--" TVD 6929 /' Completion Date 11/19/2004"""- Completion Status 1-GAS Current Status 1-GAS UIC N {f,;; ~2~.?0~00 ..zò t>y -_.._~_..'~'-'--------- ~._--~---~--,--~_. ----.-----.-----...-------. ---- ---_._-----_._-_._-_.~_._-~--~._-_.- ._~~-~_.~...__..~._-~-_._~--~".-~---~._..__._..,.--_..~._-- REQUIRED INFORMATION --~-- DATA INFORMATION Types Electric or Other Logs Run: PEX/DSI, AIT, GR/CCL, SCMT Well Log Information: Electr Digital Dataset Med/Frmt Number Mud Log No Samples No ._-~-~---_..~----_._~--_._-- --.--------.---- Directional Survey Yes _________.__.___.._____._._._._ __.,__.._.____________m____ -~-----_.__._---'------.._------..._..__._-- (data taken from Logs Portion of Master Well Data Maint Name Mud Log Report: Final Well R Log Log Run ______~cal~Me~ia./No 2 Sers' Interval Start Stop 56 8420 o 0 Mud Log Mud Log See Notes 12903 Completion og . I~ j,.{D C Pds ~/ g 12903 Completion 12904 Magnetic Resonance 3900 7846 C Pds 2 Col 2 Col 2 Col 56 8420 56 8420 56 8420 7844 8246 S// 7844 8246 3900 7846 S/ C Pds 12904 Sonic 12904 Magnetic Resonance 200 7882 12904 Sonic ....:. 1 S/'1 200 7882 C Pds 12904 Induction/Resistivity 200 7882 12904 Induction/Resistivity 25 s/1 200 7882 I r G Pd' 12905 p,rtoca'oo L------.__~~_ 8216 8236 OH/ CH Received _.._~ 12/7/2004 12/7/2004 . Comments --------1 Epoch Final Well Report I w/CD I I Drilling Dynamics Log I Combo Log ! COMPLETION RECORD 2.5" HSD POWERJETS COMPLETION RECORD 2.5" HSD POWERJETS 12/15/2004 combinable magnetic resonance tool 12/7/2004 12/7/2004 12/7/2004 12/15/2004 12/15/2004 12/15/2004 combinable magnetic resonance tool . 12/15/2004 DIPOLE SHEAR SONIC TOOL 12/15/2004 DIPOLE SHEAR SONIC TOOL 12/15/2004 PLATFORM EXPRESS W/ARRAY INDUCTION DIPOLE SHEAR SONIC TOOL 12/15/2004 PLATFORM EXPRESS W/ARRAY INDUCTION DIPOLE SHEAR SONIC TOOL 12/15/2004 PERFORATION RECORD 2.5" 2506PJ 6SPF J Permit to Drill 2041860 Pds DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Well Name/No. HAPPY VALLEY A-10 Operator UNION OIL CO OF CALIFORNIA 13267 Perforation 13267 Perforation 13268 Perforation 13268 Perforation ,HIe. ~ Completion I }gfc ~ Completion MD 8420 TVD 6929 ag-~~ ~~905-Perforãtion I cFg C Pds 12906 Cement Evaluation t Pds 12906 Cement Evaluation 1:. C ,,, ::::: :::::::::::::::::::: ~D C Pds ~ 16Jð C Pds I I Log ~ I f C Pds L Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~ Analysis Received? ~ ~,_.'--'--~'-- -~~-- Comments: Completion Date 11/19/2004 Completion Status -~----- BV -. B~ 25 Blu 25 B~ 5 B/ 1 5 Blu t'\L{' 5 Current Status 1-GAS UIC N - 8216------m6-----12/15/2004-----,:>ERFòRÄTlONRECORD' 2.5" 2506PJ 6SPF ! I 12/15/2004 SLIM CEMENT MAPPING ; TOOL i 12/15/2004 SLIM CEMENT MAPPING I TOOL I Multiple Propagation I Resistivity Gamma Ray I Multiple Propagation I Resistivity Gamma Ray Perforation Record 2" HSD I Powerjet Guns I Perforation Record 2" HSD I Powerjet Guns . Perforation Record 2.5" I ::~0~a~:~r~:C~~dn;.5" I HSD PowerJet Guns Completion Record 2" II Omega HSD 6SPF 11-Dec- 2005 I Completion Record 2" i Omega HSD 6SPF 11-Dec- . 2005 i ____~_~~.--.J 1-GAS 35200 8312 35200 8312 3860 8420 Open 7/29/2005 3860 8420 Open 7/29/2005 7675 8216 Case 7/29/2005 7675 8216 Case 7/29/2005 8090 8221 Case 7/29/2005 8090 8221 Case 7/29/2005 7250 8020 Case 5/14/2006 7250 8020 Case 5/14/2006 ,-~-~-----~~----_._-~ Interval Start Stop Sent Received Sample Set Number Comments Formation Tops Daily History Received? '(DN ~/N API No. 50-231-20028-00-00 . . -~------~----~--- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041860 Well NamelNo. HAPPY VALLEY A-10 Operator UNION OIL CO OF CALIFORNIA API No. 50-231-20028-00-00 MD 8420 TVD 6929 Completion Date 11/19/2004 Completion Status 1-GAS Current Status 1-GAS UIC N ~o:";~n"R'v;,we-';; ... .~l1b .... .. c c c.· ~~~~~~ ~ ~ ~~~~~Date~ ;;r-<11J~::~¡: . . RECE\vfo MAY 1 5 1006 Union Oil.C pany of California 909 W. 9th e Anchorage, W501 Tele: (907) 263-7889 E-mail: oudeand@chevron.com Fax: (907) 263·7828 ¡",,"It, , " C \,' 1,). Cofl\\I\\...., Debra Oudeqm)..i.1 (~\ & \;¡¡~!!,~,,\ . T echnologist Af¡(*iora<)~ Chevron Date: May 11, 2006 To: AOGCC Helen Warman 333 W. ¡th Ave. Ste#100 Anchorage, AK 99501 :....·¿õ4=išà..··· ! 502312002800 ... T"-HÄrip\lvÄLlEV~"" A10 : MUL TIFINGER IMAGING i TOOL COMPLETION RECORD 2" OMEGA HSD 6SPF 5 INCH i 7250-8020 '204-207 i 502312002900 . HAPPY VAllEY: iRÄI..LISÜFlTONMÄGNÄ ClBP A 11 i SETTING RECORD : 204-207 : 502312002900 '0.... _···."·.·M,· _.·,·M.·_··.M"___~, HAPPY VALLEY- : 2.5 POWERGET HSD GUN / A11 . PERFORATION RECORD 5 INCH 16-Nov- '6720:j190 i 05 : 5 INCH 16-Nov- i 6830:6990 '2 . 05 pds 204-207 i 502312002900 HAPPY VALLEY- ,COMPLETION RECORD . 51NCH 10-Nov-, 7990-9085 i A 11 i HALLIBURTON CISP FOR 3.5" : i 05 : CASING /2.5 HSD POWER : JET 6 SPF PERF . 1 \ 1 : pds, 1Jd 199-054 501331012501 SCU 21A-09 .. iCOMPI..ÜIONFlECOFlD 2.5" . : ... 51NCR 01-May- 10095- OMEGA HSD 6 SPF 06 10450 ...--.."'.----"---...............---,..,,.....,,.----.,-......"'---- -,-,,,,--..,-_...'. 190-147 507331005501 TBF A-01RD : COMPLETION RECORD 2 5 INCH , 02-Feb- 5300-6015 HSD POWER JETS 4SPF 06 .-,--.".".....---....---.......".-----. .' TSÜ[):01 . . ..... COMPI..ETIÖNFlECORÒá3/8 9280-9414 167-080 ¡ 507332006800 i 5 INCH 11-Feb- HSD POWER JET 6 SPF, 60 06 PHASING 198-064 507332026701 TBU G-21 RD . .. cÖMPl..EflONRECÖRD 2.25 5 INCH 29-Jan- , 9615-9833 POWERJET HSD GUNS, 4 06 SPF, 60 DEG, GAMMA RAY / CCL CORRELATION 169-086 507332049800 TBU G-32 COMPLETION RECORD 2.875 5 INCH 31-Jan- 9180-9950 POWERJET HSD GUNS, 4 06 SPF, 60 DEG, GAMMA RAY I , CCL CORRELATION 1 i pds pds , 1 \ pds 1 . pds, pdt , pds, pdt Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received By, C. ~_"--- I Date S-jWfrHf' . STATE OF ALASKA . ALA... OIL AND GAS CONSERVATION COM. ON REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 0 6 2006 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U I'lIIIIIIft:Ø ~ UL EI I Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Anchorage Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 204-186 3. Address: PO Box 196247, Anchorage, AK 99519 Stratig raph ic D Service D 6. API Number: 50-231-20028-00 7. KB Elevation (ft): 9. Well Name and Number: 16.4' RKB to TH HV-A10 8. Property Designation: 10. Field/Pool(s): Happy Valley Production Facility Happy ValleylTyonek 11. Present Well Condition Summary: Total Depth measured 8,420' feet Plugs (measured) n/a true vertical 6,929' feet Junk (measured) n/a Effective Depth measured 8,348' feet true vertical 6,861' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' 5,380 psi 2,670 psi Surface 941' 9-5/8" 941' 924' 5,750 psi 3,090 psi Intermediate 3,850' 7" 3,850' 2,995' 7,240 psi 5,410 psi Production Liner 4,785' 3-1/2" 8,416' 6,925' 1 0,160 psi 10,530 psi Perforation depth: Measured depth: 7,844 to 8,246' True Vertical depth: 6,383 to 6,763' Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 @ 3,660' Packers and SSSV (type and measured depth) Baker ZXP Packer@ 3,616' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a RBDMS 8Fl JAN 0 9 2D06 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: n/a 3.7 0 n/a 864 Subsequent to operation: n/a 4.4 0 n/a 900 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Service D Daily Report of Well Operations X 16. Well Status after proposed work: OilD Gas D WAG 0 GINJ D WINJ D WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. \SUndry Number or N/A if C.O. Exempt: n/a Contact Steve Tyler 263-7649 Printed Name Timothy C. Brande~12urg ~ Title Drilling Manager ~ ",. L/ /) IJ~/Ol.p Signature l' -- L-": é'/../ Phone 907-276-7600 Date _ .J'" Form 1 0-404 Revi~écÍ 04/2004 ORffi AFE 164759 Submit Original Only on lNAL . API: 50-231-20028 AOGCC: 204-186 1118'FSL, 129~FEL Sec22 , T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3%" IBT Tree cxn - 2%" Bowen cxn Production Tubino: 3%", 9.2 ppf, L-80, IBT-Mod to 3660' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection sidepocket mandrel at 2502' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3626" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3660' Slickline tagged fill at 8255' (3/22/05) Directional Data: max hole angle = 49.2 deg at 1920' KOP = 300' max doglegs = 4.2 deg/100' at 547' 5.1 deg/100' at 1037' 3.5 deg/100' at 4077' HV-10 Actual schematic 12-11-2005 · · · · · · · · · · · ... PBTD = 8348' TD = 8420' . Well Name: Happy Valley A 10 Field: Deep Creek Unit State: Alaska Conductor: 13%", 72 ppf, N-80 to 73' Surface Casino: 9%", 40 ppf, L-80, BTC-Mod to 941' Cmnt with 46 bbl of 12.8 ppg lead and 31 bbl of 15.8 ppg tail "G". FIT = 14.8 ppg EMW Intermediate Casino: 7", 26 ppf, L-80, BTC-Mod to 3850' Cmnt with 75 bbl of 12.8 ppg lead and 14 bbl of 15.8 ppg tail "G". LOT = 13.8 ppg EMW Open Perfs: T-10: 7,885' -7,830' (6 spf 12/11/05) T-10: 7844' - 7854' (6 spf, 11/19/04) T-17: 8198' - 8246' (6 spf, 11/10 & 11/19/04) T-17: 8,218' - 8,246' (5/2/05) T-17: 8198' - 8,228' (5/4/05) T-10: 7,844' - 7,854' (5/5/05) Isolated Perfs none Production Liner: 3%", 9.2 ppf, L-80, IBT-Mod liner from 3631' - 8416' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3616' Cemented with 155 bbl of 12.0 ppg Litecrete Updated by: DED Daily Operations 12/10/200500:00 -12/11/2005 00:00 Operations Summary Plan forward: Have Schlumberger on location at 7 AM, 12-11-05 12/11/2005 00:00 - 12/12/2005 00:00 Operations Summary MI/RU. PJSM. RIH w/2" X 30" Omega HC, 6 SPF, 60-deg perf gun. Tie in with Schlumberger log dated 11-1-04. Reperf 7,885' to 7,855'. All shots fired. RIH w/2" x 30" Omega He, 6 SPF, 60-deg perf gun. Tie in with Schlumberger log dated 11-1-04. Reperf 7,855' to 7,830'. All shots fired. RD Schlumberger. Turn well over to production. J_ ¡ :i-" ¡~... '\ , ; ! ,~ ¡ Þ ¡ i','~ ;1 ~ } = \ IJ U U . ! I 1 f ! / FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COMMISSION I J November 9, 2005 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501·3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Mr. Larry Greenstein UNOCAL [Chevron] P.O. Box 196247 Anchorage, Alaska 99519 ¿~J)4-'ë7t~ It-I Ó Dear Mr. Greenstein: The Alaska Oil and Gas Conservation CommissionT'Commission") performed an inspection of your well safety valve system (SVS) at Deep Creek Unit, Happy Valley "A" pad on November 1, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 553 requires all development wells to be equipped with a fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead. An SVS component failure rate of 30 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. The Commission inspector identified freezing as the cause of failure, preventing the SSV from closing on wells A-2, - 8, and -9. Effective November 1,2005 and until an acceptable level ofperforrnance is achieved, the safety valve systems associated with wells located on Happy Valley A-pad must be tested every 90 days. When testing is scheduled, you must notify the Commission (907-793-1236; 907-659-2714 on weekends and after hours) at least 24 hours in advance to provide an opportunity to witness the SVS test. Unocal mast also provide the Commission with a written summary of the work to be completed to ensure the SVS is operational, specifically addressing the freezing concerns that prevented the SSVs to function properly when tested. Sincerely, ~: --;-") '---:--> ,,,j1,,u~b, K~1 James B. Regg 7 Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors Safety Valve & Well Pressures Test Report Reviewed By: P.l. Suprv Comm Pad; DC_HAPPY_VALLEY_A Insp Dt 11/1/2005 Inspected by Lou Grimaldi Interval 90 Days InspNo svsL0051102044246 Related IlIsp: Field Name DEEP CREEK Operator UNION OIL CO OF CALIFORNIA Operator Rep Steele/Tresler Reason 1 SO-Day Src: Inspector Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code 1!=j~~-t1~li!~f!Ir~}~ItEfl~~I .. Date SI OiI,WAG,GlNJ, Inner Outer Tubing GAS, CYCLE, SI PSI PSI PSI Yes/No Yes/No _=~t - ~.. fJJ1J-~~J-t1r[m _.. . _ '~-l __U~ Comments Performance ____,..____"___u_ _~~..m ..,"..~__ .-."-...---,..-->-- wells 2,8,&9 failed to close, appeared to be froze Pad manned and wells observed, heaters will be applied and valves thawed and successfully retested by 12:00 11/02/05 or be shut-in. Outstanding equipment setup and appearance of maintenance. Wells Components Failures 10 ------- ,.. ~~-_._.- Failure Rate ._J.Qr<>._ ...-----...-. .-- -.' ---"-._---_....__..._~--- .-._~._---_...__.-.---.- _._-'-- . f o p y Wednesday, November 02, 2005 Debra Oudean G & G Technician To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 . UnocaJ Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263·7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCAL . Date: July 27, 2005 PERFORATION RECORD 2 HSD POWERJET GUNS PERFORÄTioN " RECORD 2 HSD POWERJETGUNS MULTIPLE PROPAGATION RESISTIVITY m GilMMilfto\YMD MULTIPLE PROPAGATION RESISTIVITY GAMMA RAY ND GÄMMÄRAYfCCL COMPLETION RECORD 2.5 HSD Pºvv~flJ~IS COMPLETION RECORD 2.5 HSD POWERJETS COMPLETiON RECORD 2.5 HSD POWERJETS COMPLETION RECORD 2.5 HSD POWERJETS .........--,.......,'...---.....-.... COMPLETION RECORD 2.5 HSD POWERJETS 6 SPF, 60 DEGREE PHAZED côMpLETioN " RECORD WEATHERFORD WRP PLUG COMPLETIÔN RECORD 2.5 HSD POWERJETS 6 SPF ., 'cÔMPLffíÔNm . RECORD HALLIBURTON FASDRILL BRIDGE :P~LJG Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. . 204-186 . ·'5ó2~Ù20ó2àoo HÄFipy,\ïÄLLEY~1-ò" 204-186 ..-.-......--.....,.......----...--...."..---.. 502312002800 HAPPY VALLEY -10 , 204-186 . ... . "... "" -,... 502312002800 HAPPY VALLEY-I 0 204·207 ., ,.'u__...__.." ..".......".,.....w.......__..._. 502312002900 HAPPY VALLEY -11 204-207 502312002900HAPPYVAllEY:jj 204-207 502312002900HÄPp¥vALlÊY: 1i 204-207 502312002900HÄPPY VAŒÊy-ii 204-207 502312002900 HAPPY VALLEY-11 203-222 ..,"" !5Ò2312ÕÒ160Ò" HÃpp'i\iALLÊY~3-----' 204-114 50231'2002300 'HÄPPY"'V'ÃLCEy:if' 204-114 Só2á120Ó230Õ"" 'HÃppV\/Ã[LEy~8" v òJkj Received By: s INCH " ....."...---.........---......--. 02-May·05 8090·8221 215 INCH 11-0ct-04 3860-8420 215 INCH 11-0ct-04 3860·8420 5 INCH 30-Nov·04 7000-10003 5 INCH 03-Dec-04 9530-9654 siNCH" 04·Dec-04 9104·9154 S iNCH . 01-Dec·04 9262-9636 5 INCH 10-Dec-04 9260-9640 5 INCH "·_,,,'v·..-·'·'·'·,_,_·'·'·...·..w 19-Apr-04 ,_·w·,,··_·_··,,···___~···__·-',·, 10270-10545 5 INCH ,...........'.,-.,..-.'_._-".,_.......,-.-.-.-......-, 09-Mar-05 3900-8440 sÎNCH 09~beé-ö4 ....,.,~~,-.._'.'......,.._._,~<......_..., 4020-5630 J/ l..r 0 --f" 0 pds i1,: "':..¡¡¡"...... j'H .> "À, ~Co ". ........,...........--........-'''...--.........-. 1 las, metafile, viewer pds pds pds pds pds o pds pds I Date' Ji- ~ A~~r- ':)..0'--( - \ 8 \0 P'~ \ t. 204·170 HAPPY VALLEY-9 COMPLETION RECORD 2.5 HSD . RECORD HALLIBURTON FASDRILL BRIDGE SINCH 6300-7500 . 1 dlis.fma,pds Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. 18-Dec-04 Received By: I Date: . STATE OF ALASKA ALAS lLANO GAS CONSERVATION COMMIA.)N REPORT OF SUNDRY WELL OPERA'TiONS ,JUN 0 {; 2005 ", . "I" i" " 1. Operations Abandon U Repair Well U Plug Perforations 0 StimulateU 'ðlRé'r B ~ept9rfóýát& Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension Dee ",; ::, Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Name: Development [2] Exploratory D 204-186 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic D Service D 6. API Number: 50-231-20028 7. KB Elevation (ft): 9. Well Name and Number: 733' HV-A10 8. Property Designation: 10. Field/Pool(s): Happy Valley Production Facility Happy Valley FieldlTyonek 11. Present Well Condition Summary: Total Depth measured 8,420' feet Plugs (measured) n/a true vertical 6,929' feet Junk (measured) n/a Effective Depth measured 8,348' feet true vertical 6,861' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' 5,380 psi 2,670 psi Surface 941' 9-5/8" 941' 924' 5,750 psi 3,090 psi Intermediate 3,850' 7" 3,850' 2,995' 7,240 psi 5,410 psi Production Liner 4,785 3-1/2" 8,416' 6,925' 10,160 psi 10,530 psi Perforation depth: Measured depth: 7,844 to 8,246' True Vertical depth: 6,383 to 6,763' Tubing: (size, grade, and measured depth) 3-1/2" 9.2 ppf L-80 @ 3,660' Packers and SSSV (type and measured depth) Baker ZXP packer @ 3,616' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 2,800 0 0 1,100 Subsequent to operation: 0 3,600 0 0 1,380 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory n Development r71 Service n Daily Report of Well Operations X 16. Well Status after proposed work: oilD Gas [2] WAG D GINJ D WINJ D WDSPL D 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 J. Gary Eller 263-7848 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature'Z "'(?1 C ~ h ~ Phone 907-276-7600 Date 6/2/2005 './ '--' ?/ RBD MS 8Ft ,/UN 0 7 2U05 Form 10-404 Revised 04/2004 Submit Original Only Well Name HV-A10 Primary Job Type Perforating Jobs Field Name API/UWI Happy Valley Field 50-231-20028 164019 eller Daily Operations 5/21200500:00 - 5/31200500:00 Operations Summary RU electric line. Reperf T-17 Sand 8218'-8246'. POOH. Tools blown uphole when reached 168', guns stuck. Sheared out of stuck guns, recovered all wire. RD electric line. 5/312005 00:00 - 5/4/2005 00:00 Operations Summary RU slickline. Tag fish at 7750' with impression block. RIH with pulling tool, latched fish. POOH, full recovery of fish. RD slickline. 5/41200500:00·5/5/200500:00 Operations Summary RU electric line. Reperf T-17 8198'-8228'. Flow well overnight. 5/5/2005 00:00 - 5/6/2005 00:00 Operations Summary Reperforate T-10, 7844' - 7854', POOH. RDMO electric line. . UNOCALe API: 50-231-20028 AOGCC: 204-186 1118' FSL, 1296'FEL Sec22, T2S, R13VV, S.M. RT-THF: 16.4' Tbg lift threads - 3%" IBT Tree cxn - 2%" Bowen cxn Production Tubina: 3%", 9.2 ppf, L-80, IBT-Mod to 3660' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection sidepocket mandrel at 2502' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3626" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3660' Slickline tagged fill at 8255' (3/22/05) Directional Data: max hole angle = 49.2 deg at 1920' KOP = 300' max doglegs = 4.2 deg/100' at 547' 5.1 deg/100' at 1037' 3.5 deg/100' at 4077' HV-10 Actual schematic 4-18-2005 · · · · · · · · · · · · · ... . Well Name: Happy Valley A 10 Field: Deep Creek Unit State: Alaska Conductor: 13%", 72 ppf, N-80 to 73' Surface Casino: 9%",40 ppf, L-80, BTC-Mod to 941' Cmnt with 46 bbl of 12.8 ppg lead and 31 bbl of 15.8 ppg tail "G". FIT = 14.8 ppg EMW Intermediate Casino: 7", 26 ppf, L-80, BTC-Mod to 3850' Cmnt with 75 bbl of 12.8 ppg lead and 14 bbl of 15.8 ppg tail "G". LOT = 13.8 ppg EMW Open Perfs: T-10: 7844' - 7854' (6 spf, 11/19/04) T-17: 8198' - 8246' (6 spf, 11/10 & 11/19/04) T-17: 8,218' - 8,246' (5/2/05) T-17: 8198' - 8,228' (5/4/05) T-10: 7,844' - 7,854' (5/5/05) Isolated Perfs none Production Liner: 3%", 9.2 ppf, L-80, IBT-Mod liner from 3631' - 8416' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3616' Cemented with 155 bbl of 12.0 ppg Litecrete Updated by: JGE · Transmittal Form Unocal Alaska Regulatory Filing UNOCAL Date: (j rip (DS ---,.., Submitted by: 1)(/ nha W1 Well Name:~ Project Manager:{;j/VV Type of Form: 0 AOGCC 10-401 o A~GCC 10-403 2"'ÃOGCC 10-404 o AOGCC 10-407 o BlM 3160-05 (Notice of Intent) o BlM 3160-05 (Subsequent Report) Sent to: 0 Bureau of land Management 6881 Abbot loop Anchorage, AK 99507 ~OGCC 333 W. ih Avenue .Anchorage, AK 99501 Sent via: o Mail o Courier rEf'6riÍling Personnel Page 1 of 1 STATE OF ALASKA ALAS. AND GAS CONSERVATION COMMIS. WELL COMPLETldW OR RECOMPLETION RÈi50RT AND LOGp.N ~2 ~ OilLJ Gas0 Plugged 0 AbandonedU 20AAC 25.105 GINJD WINJD WDSPLD No. of Completions 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519-6247 4a. Location of Well (Governmental Section): Surface: 1118 FSL, 1296 FEL Sec. 22 T2S R13W SM Top of Productive Horizon: 1559 FNL 646 FWL Sec. 22, T2S, R13W, SM 1 a. Well Status: Total Depth: 1445 FNL, 503 FWL Sec. 22, T2S, R13W, SM 4b. Location of Well (State Base Plane Coordinates): Surface: X = 227,968, Y = 2,189,662 TPI: X = 224,698, Y = 2,192,311 Total Depth: X = 224,558Y = 2,192,429 18. Directional Survey: Yes 0 No 0 21. Logs Run: PEXlDSI, AIT, GRlCCL, SCMT . WAGD 1b. Well Class: ."<' i;~,'" ¡ ',;l;; Development 0~, \':,.ig¡:iWtìarory r:¡n~~ Service 0 Stratigraphic Te~fU' . ,.: 12. Permit to Drill Number: 204-186 13. API Number: 50-231-20028 14. Well Name and Number: HV-A10 15. Field/Pool(s): Happy Valley Field Beluga/Upper Tyonek Suspended U 20AAC 25.110 1 Other 5. Date Comp., Susp., or Aband.: 11/19/04 6. Date Spudded: September 27,2004 7. Date TD Reached: October 12, 2004 8. KB Elevation (ft): 733' 9. Plug Back Depth(MD+ TVD): 8,348/6,861' 10. Total Depth (MD + TVD): 8,420/6,929' 11. Depth Where SSSV Set: n/a 19. Water Depth, if Offshore: n/a feet MSL 16. Property Designation: C-061590 17. Land Use Permit: n/a 20. Thickness of Permafrost: n/a 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8" 72# L-80 0 73' 0 73' Driven See Schematic for cement detail. 9-5/8" 40# L-80 0 941 0 924' 12-112" 7" 26# L-80 0 3,850 0 2,995' 8-1/2" 3-1/2'" 9.2# L-80 3631' 8416' 2,846' 6,925' 6-1/8" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): T-10: 7844' -7854' (6 spf, 11/19/04) T-17 8198' - 8146' (6 spf, 11/10 & 11/19/04) 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 3,660' 3,616' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Water-Bbl: o Water-Bbl: o Choke Size: ¡GaS-Oil Ratio: Oil Gravity - API (carr): I\L [;j...."...... .~ -".' ...," ..,.:..:....".......-' '.~._, ..-.......,1..;.,........., ...;»........ '...v....'..........................'. ..... ,f-;¡ '..J., C,: ";i,\'..' " < """"". fØ/:;. L: ~-tf. IV~';" -LIL~u : .----.. ,,_-....,---,," .,..., ~J- 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): November 13, 2004 Flowina Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: 11/15/2004 1/6/1900 Test Period ...... 0 584 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Press. 1200 0 24-Hour Rate -+ 0 2335 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". CORE # BARREL TOP BASE CUT 1 2-5/8"x90' 4503 4510 7 2 2-518"x90' 4546 4636 90 3 2-5/8"x90' 7828 7859 31 REC. 3.5 90 2.5 (%) 0.50 1.00 0.08 DESCRIPTION BLG-40: grey organic-rich claystone Oammed) BLG-40: full recovery T10: jammed 2005 (~ RBDMS BFt .IAN 3 f ¡ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ u ..... ftl" VfUL.I" 28. GEOLOGIC MARKERS NAME TVD 2,208 2,632 2,767 3,049 3,666 3,856 4,887 5,796 5,811 6,044 6,100 6,237 6,293 6,370 6,450 6,704 Beluga MTL9 MTL8 MTL7 MTL6 BLG-45 MTL3 Tyonek T1TOP T5 TOP T6 TOP T7 TOP T8 TOP T10 TOP T12 TOP T17 TOP 2, 3,317 3,516 3,930 4,726 4,959 6,187 7,211 7,228 7,480 7,541 7,688 7,747 7,830 7,915 8,184 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: 29. Include and briefly s detailed supporting d "None". FORMATION TESTS ize test results. List intervals tested, and attach necessary. If no tests were conducted, state None Contact: Steven S. Lambe 263-7637 Title: Drilling Manager INSTRUCTIONS Phone: 907-276-7600 Date: 1/20/2005 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 20: True vertical thickness. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 .~.'\ l.~ . ¡ , CONFIDENTIAl . UNOCALfJ) API: 50-231-20028 AOGCC: 204-186 1118'FSL,1296'FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3y." IBT Tree cxn - 2y." Bowen cxn Production Tubina: 3Y.", 9.2 ppf, L-80, 1ST-Mod to 3660' - Annulus loaded with 3% KCI brine plus corrosion inhibitor ComDletion - Chemical injection sidepocket mandrel at 2502' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3626" - Baker 80-40 seal assembly 13' of 4.00" aD seals - Muleshoe at 3660' Directional Data: max hole angle = 49.2 deg at 1920' KOP = 300' max doglegs = 4.2 deg/100' at 547' 5.1 deg/100' at 1037' 3.5 deg/100' at 4077' HV-10 Actual schematic 11-22-2004 · · · · · · · · · · · · · · · ... . Well Name: Happy Valley #10 Field: Deep Creek Unit State: Alaska Conductor: 13%",72 ppf, N-80 to 73' Surface CasinQ: 9%", 40 ppf, L-80, STC-Mod to 941' Cmnt with 46 bbl of 12.8 ppg lead and 31 bbl of 15.8 ppg tail "G". FIT = 14.8 ppg EMW Intermediate CasinQ: 7", 26 ppf, L-80, BTC-Mod to 3850' Cmnt with 75 bbl of 12.8 ppg lead and 14 bbJ of 15.8 ppg tail "G". LOT = 13.8 ppg EMW aDen Perfs: T-10: 7844' - 7854' (6 spf, 11/19/04) T-17: 8198' - 8146' (6 spf, 11/10 & 11/19/04) Isolated Perfs none Production Liner: 3Y.", 9.2 ppf, L-80, IBT-Mod liner from 3631' - 8416' Baker ZXP packer, Flexloèk liner hanger & 80-40 sealbore at 3616' Cemented with 155 bbl of-12.0 ppg Litecrete CONFtOENTtAt Updated by: JGE . . 9/26/04 MIIRU 9/27/04 MIRU. Drl12 1/4" hole from 53' to 350' and 12 1/4". Drl directional hole from 350' to 955'. Circ Bottoms up. Circ nut plug sweep and carbide sweep around. Indicated a gauge hole. POOH. LD BHA. 9/28/04 RU Weatherford. PJSM. RIH with 22 joints 9 5/8". PU landing joint and land casing. RU cement manifold. RD Weatherford. PJSM. Pump 3 bbls H20 ahead with OS. PT lines to 4000 psi. Pump 30 bbls mud push XL. Mix and pump 46 bbls Lead "G", with 0.2% 0046,1% S002, 1.5% 0079 to a slurry weight of 12.8 PPG, followed by 31 bbls Tail "G" with 0.2% 0046, 0.3% 0065,1.5% S002 to a slurry weight of 15.8 ppg. SO and drop plug and follow with 5 bbls H20. Displace with rig pump with 65 bbls mud. Plug bumped. (CIP = 18:40 Hrs) Got +1.20 bbls contaminated cement back. Pressure up to 3500 psi and hold for 30 min -- OK. Floats held. RD NO riser. Pull slip lock adapter and set MBS well head. Test neck seals on 9 5/8" hanger to 5000 psi and hold 20 min. NU BOPE. Function test rams. Test gas alarms and connect choke lines to stack. Clear floor and RU to test BOPs. 9/29/04 Finish test BOPs to 250 psi low and 3500 psi high. Install wear bushing. PU/MU BHA #2. RIH picking up 5" HWDP and 61/2" jars. Run 4" HWDP from drk. PJSM, wash down and tag cement and wiper plug at 894'. CBU Drl wiper plug, float collar and 10' of new hole to 965'. CBU 90% sand. (Float collar at 896', shoe at 937' BTM at 955' DPM). Conducted FIT test with Schlumberger cement pump at 1/4 bbl per minute. Pressure up to 300 psi, with 9.1 ppg water base mud without break. Shut off pump 10 see reading was 275 psi. (casing shoe 926' TVD EMW 14.8 ppg). Drl 8-1/2" directional hole from 965' to 1781'. Drl from 970' to 985' high side. Drl from 970' to 1728'. 9/30/04 Continue drl 8 1/2" directional to 2792'. PU to ream and make connection (pumps on and no rotary.) Pull20K over. Unable to go up or down or rotate. Retained full circulation. Jar and work stuck pipe both down and up . Attempt work torque slump down. Max Pull = 1 OOK over. MU OBM base oil pill and pump and spot as balanced plug with top at 1783'. Left 8 bbls OBM/in drl string. Pill in place at 17:30 hrs. Service crown and inspect drk after jarring. Continue jar and work pipe up and down. Also torque slump. Down. Monitor well. No losses. Pump 1) bbl OBM (7 bbls left in drl string.) Continue jar and work pipe up and down and torque slump down. Max Pull 156K/over. Monitor Well. No losses (good circulation. 1 bbl in/1 bbl out.) 10/1/04 Pump 1 bbl OBM at mid-pm and 1 bbl OBM at 02:30. Monitor well and jar and work stuck pipe without success. RU APRS in drk. MU swivel and side entry sub on joint of drl pipe. Make up free point tools and RIH same. Run free point below jars. Pipe checked up to be 100% free to the top of MWD, POOH. Make up 450 grain string shot. RIH to 2700'. Perform controlled back off.--did not get back off. POOH. Make up 475 grain string shot. RIH with string shot to 2700'. PJSM on backing off pipe. Perform controlled back off. Broke connection first flex collar above MWD. POOH. RD APRS. Make up top drive and apply 2 more rounds to left to finish backing off pipe. up weight 80 kip. Up weight was 84 kip before pipe was stuck. Circ we II bore clean. POOH with no problems. Top of fish at 2686' per drl pipe strap out of hole. LD two flex collars. Make up 4 1/2" H-90 screw in sub + bumper sub and jars. RIH picking up 9,6-1/2" drl collars. LD drl jars. 10/2/04 RIH with fishing assembly and tag fish at 2686'. CBU. Screw into and catch fish. Work down hitting bump sub. Pipe Free. Circ and work up through tight hole and ream back through bottom at 2792'. Check MWD. No Pulse. Drl8 1/2" hole from 2792' to 2823'. Circ bottom up, POOH to Shoe. Wash and ream from 2350' to 1350'. Straight pull from 1350'. CBU at shoe. Screens cleaned up. Remove APRS sheave from drk. POOH to last 2 joints of 5" HV-10 (163066) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 1. HWDP. LD fsg assy. LD fish (b.tor, MWD, lead collar, stab, flex collar.) ear sub had 3/8" chain link in it. LD APRS side-entry sub. PU and MU BHA #4. RIH with BHA #4 1 0/3/04 RIH. Test MWD at shoe. Safety wash and ream from 2728' to 2823'. Drl 81/2" directional hole from 2823' to 3860'. Circ, pump LCM and carbide sweeps. Indicates < gauge hole. Short Wiper Trip to 2600'. Various tight spots starting at 3300'. Pump on from 3272'. Work through tight spots rotary and pump. RIH to bottom without pump or rotary. Circ and condition mud to run 7" casing. POOH. Monitor well at shoe (static 15 min .6 = 2.4 bph.) LD 5" HWDP. Dr11037' in 10.9 hrs. 10/4/04 Finish LD HWDP and smart iron BHA. Pull wear bushing. RU to run 7" casing. Run 92 joints and 1 pup of 26#, 7" casing. PU hanger and land. Circ for cement job. RU cement head and Dowell lines. PT lines to 4000 psi -- OK. Pump 30 bbls mudpush XL with rig. Mix and pump 75 bbls Lead slurry at 12.8 ppg, followed by 14 bbls Tail slurry at 15.8 ppg. Drop plug, followed by 5 bbls. Mix H20. Finish displacement with 139.2 bbls mud with rig pump. Plug bumped on time. PT to 3500 psi and hold. CIP = 11 :45 hrs. After 17 min of 3500 psi casing test pressure was bled off. RD DSLD landing joint and RU seal assembly. PU 5" HWDP and set 7" pack off with top-drive and test to 4300 psi. Change bottom rams from 7" to 3.5" and PT door seals to 3000 psi. Pull test plug and install wear bushing. RU to PU BHA. PU and MU 3 flex collars and 4" HWDP (5 joints). RIH with 4" HWDP out of drk. PU and MU 4" DP. 10/5/04 RIH PU DP to 3752'. Fill DP; break circulation. Circ through the choke manifold; tested the 7" casing to 3500 psi for 30 min. Perform choke drl. Drl FC and cement; FC at 3765'; drl out shoe at 3848'. Drl to 3880'. Circ and displace the hole to new mud. Perform LOT 13.8 ppg EMW. Drl from 3880' to 3943'. Drl from 3943' to 4503'. POH. 10/6/04 PU 90' cg assy and install inner 25/8" ID barrels. RIH 90' with cg assy. Cr 4507' to 4510'. Cr jammed, PU and saw no break off. Circ up sample. POOH with cg assy. LD bottom bbl and recover 3' of clay stone cr. PU new cr bbl and catcher, rack cg assy in drk. Make up 61/8" drl assy. RIH to shoe at 3850'. Break circulation, continue RIH, to bottom at 4510' -- l' fill. CBU. Drl from 4510' - 4545' at 5' intervals and CBU looking for sand. Projected survey at cr point 4545' MD, 3519.54' TVD, Inc 35.11, AZ 307.50. POOH with drl assy -- OK. Work BHA, rack back drl assy and MU cg assy. RIH with coring assy. 1017104 RIH to 3672'; fill pipe; RIH to 4450'.Circ the last stand down to 4545' without tagging bottom. Begin core at 03:00 hrs. Core from 4546'. Core from 4546' to 4636' with 6.125" cr bit. CBU. POH with core and core assy. Retrieve core from core bbl and LD same; stand core bbl back. PU drl assy and RIH; Plug in MWD and shallow test. RIH to shoe; fill pipe; finish RIH to 4546'. Clean out hole to bottom while making a pass from 4546' to 4636'. Drl from 4636' to 4975' at midnight. 1018104 Drl from 4975' to 5932'. CBU. Drl from 5932' - 6104' 10109/04 Drl from 6104' to 7131 '. Make short trip to 6090' (Tight 20 -35 kip 6652' and 6409',6333'.) Straight pull without pump. RIH. Set down at 7101'. Drl7131' to 7606'. 10/10104 HV-10 (163066) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 2. Drl from 7606' to 7828'. CBU . for core assy. Work BHA, download M&IH with core assy set down at 7177' 10 KIP. Continue RIH, Wash and ream the last 60' to bottom at 7828'.Drop ball and circ down and shift sleeve for core ops. Core from 7828' to 7859'. Core bbl believed to be jammed. 10/11/04 POH. Cr 7828' - 7859. l' MD Recovered 2' cr; LD cg assy. PU drl BHA, RIH to the shoe and fill pipe. Remove weight indicators from drlline and slip cut drlline. Test BOPs. RIH from shoe to 7731'. Log from 7817' to 7859. Drl from 7859' to 8331' at midnight. 10/12/04 Drl from 8331 to 8420' (6,929 TVD); TD of 6 1/8 OH. CBU. 7 std short trip to 7758'; coal ledges at 7900-7868. Circ POH to run E-Iogs. RU SCHL to run PEX/DSI log. RIH. GR from 7868' to surface. LD PEX/DSI tool; PU CMR tool. RIH to 1650', POH weight up. RIH to 2700'. RU to test BOP; PU 4" test joint, test 250/3500 psi. PU 3.5" test joint and test; test variables 250/3500psi. Tested choke manifold 250/3500 psi with wireline. 10/13/04 RD test equipment; RIH and set wear ring. RU e-line, PU CMR tool and RIH to 7868', Log out. RD SCHL. Rig to run 3 1/2" liner. RU Weatherford casing service. RIH with 3 1/2" liner 148 joints + 4 pups 4,802' including hanger equipment. Filling pipe each 10 stnds. CBU at shoe. Continue running 3 1/2" liner. Make up hanger assy. RD. PU 4" HT-38 SWDP and continue running liner on 4" DP. RIH to 7,827. Washed down from 7,827 to 8, 108. 10/14/04 Cont RIH with liner took weight at 8,256 liner on bottom. Wash down to 8,420 . CBU and PJSM at 05:00 hrs. RU Cement test lines, pump chemical wash. mud push and pump 12 ppg Litecrete. Bump plug with 5 bbls of water and 71.1 bbls of 3% KCL water. CIP at 06:00 hrs pressure up to 3500 psi and hold; slack off weight on hanger, bleed pressure off back to SCHL, set slips and rotate 19 turns to right, PU and set down on locking dogs to set packer, test packer to 2000 psi--OK. Line up on 8.5 ppg 3 % KCL water and displace hole to KCL; held 500 psi on tubing while picking up out of seal bore. RD cmt and circ hoses/chic-sans. POH LD DP. LD running tools. RIH with DP stands; POH LD DP. Pull wear ring; PU seal assy. RIH with 3-1/2 tbg/completion. PU S01 Mandrel, RU sheave in drk, test control line to 1000 psi/10 min; RIH with 3 %" tbg. 10/15/04 RIH with 3 1/2 tbg and space out. MU hanger, splice control line and test, pump freeze protect and displace, land out and test tbg. Test tbg for 30 min; 3535psi bled to 3485. Test casing for 30 min, drop 25 psi. Install BPV. Clean pits and drk, freeze protect lines, service rig and maintenance. 10/16/04 RD 10/17/04 Rig on standby. 10/18104 Rig on standby. 10/19/04 Rig on standby. 10/20/04 HV-10 (163066) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 3. Rig on standby. . . 10/21/04 Rig on standby. Logging from 2200' tl700' at1800 FPH and pull repeat pass from 1100' tI 700' Bleed off applied pressure on csg and RD and leave location. 11/1/04 MIRU SCHL wireline, test lubricator to 2500 psi. Run cement log under 1500 psi as per program. Tie in Log = SCHL AIT Log dated Oct. 12,2004. Top of cement at 4460'. 11/2/04 MIRU coil tubing. 11/3/04 MIRU coil tubing. Test coil, injector and surface line to 1500 psi with nitrogen. RIH with wash nozzle on dry coil tubing and tag BPTD at 8319' coil tubing measurements, Displace KCL fluid from tubing with nitrogen. Recovered 70 more bbl in Johnson tank. POOH coil tubing and leave 1300 psi Nitrogen cap on tubing. RD coil tubing. Rig down coil tubing and move out same. 11/10105 RU SCHL. PJSM. Pressure test from upper master to lubricator and flow line to 3500 psi. RIH with 20' of 2-1/2",6 spf at 60 deg phased hollow carrier gun loaded with 10.5 grams PJ2506 charges. Tie in to SCHL cement log dated 11/01/04 and perforated T-17 interval from 8214 - 8234' at 17:55 hrs with 1250 psi N2 cap for under balance. 50 psi in first 20 min. SCHL POOH check gun all shots fired. RU to 1961 psi. 11/19/04 Well is flowing to sales at 2.57 mmcfd with 1205 psi FTP on an 18/64" choke at the line heater. MIRU SCHL electric line without shutting in well. PJSM and pressure test lubricator to 3000 psi using. Perforate the T-17 Sand at 8236' - 8246'. Perforating under balance approximately 1600 psi. POOH. All shots fired. Well producing 2.72 mmcfd with 1258 psi FTP. RIH. Tie Perf the T-17 Sand at 8198' - 8216'. Perforating under balance approximately 1500 psi. POOH. All shots fired. Well now producing 3.1 mmcfd with 1365 psi FTP. RIH. Perf the T-10 Sand at 7844' - 7854' . Perforating under balance approximately 1300 psi. POOH. All shots fired. Well now producing FTP. RDMO SCHL. 12/1/04 to 12/6/04 RDMO HV-10 (163066) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 4. >Information >Well >Directional Surveys >F.rvey . Select Well: HV10 - Name Well Date Created Position Log HV10 1/19/2005 Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) HV10 GAS 502312002800 733 227,968 2,189,662 TVD SSrvD X Off YOff X Y Inc Azimuth (ft) (ft) (ft) (ft) (ft) (ft) (deg) (deg) 0 0 733 0 0 227,968 2,189,662 0.0 0 176 175 558 0 0 227,968 2,189,662 0.6 321 238 237 496 0 1 227,968 2,189,663 0.7 329 300 299 434 -1 2 227,967 2,189,664 361 360 373 -3 3 Inconsistant Data 227,965 2,189,665 Click HERE to view Directional Survey. 423 422 311 -5 6 227,963 2,189,668 485 484 249 -9 10 227,959 2,189,672 547 546 187 -15 16 227,953 2,189,678 608 606 127 -23 22 227,945 2,189,684 671 667 66 -34 31 227,934 2,189,693 733 727 6 -46 41 227,922 2,189,703 796 787 -55 -59 53 227,909 2,189,715 859 847 -115 -74 66 227,894 2,189,728 890 877 -145 -81 72 227,887 2,189,734 1,037 1,012 -280 -127 107 227,841 2,189,769 1,131 1,095 -363 -161 133 227,807 2,189,795 1,226 1,177 -445 -199 162 227,769 2,189,824 1,289 1,230 -498 -226 183 227,742 2,189,845 1,352 1,282 -550 -254 205 227,714 2,189,867 1,415 1,334 -602 -283 228 227,685 2,189,890 1,478 1,383 -651 -313 253 227,655 2,189,915 1,541 1,431 -699 -344 280 227,624 2,189,942 1,604 1,477 -745 -377 307 227,591 2,189,969 1,667 1,522 -790 -412 336 227,556 2,189,998 1,730 1,565 -833 -447 364 227,521 2,190,026 1,794 1,609 -877 -483 394 227,485 2,190,056 1,857 1,652 -920 -518 423 227,450 2,190,085 1,920 1,694 -962 -554 453 227,414 2,190,115 2,046 1,777 -1,045 -628 514 227,340 2,190,176 2,172 1,860 -1,128 -701 574 227,267 2,190,236 2,299 1,944 -1,212 -775 633 227,193 2,190,295 2,425 2,028 -1,296 -849 692 227,119 2,190,354 2,551 2,112 -1,380 -922 750 227,046 2,190,412 2,678 2,198 -1,466 -996 809 226,972 2,190,471 2,771 2,260 -1,528 -1,049 851 226,919 2,190,513 2,898 2,347 -1,615 -1,121 911 226,847 2,190,573 3,024 2,432 -1,700 -1,192 970 226,776 2,190,632 3,150 2,518 -1,786 -1,263 1,029 226,705 2,190,691 3,276 2,604 -1,872 -1,334 1,088 226,634 2,190,750 3,403 2,690 -1,958 -1,406 1,146 226,562 2,190,808 3,529 2,776 -2,044 -1,477 1,206 226,491 2,190,868 3,655 2,862 -2,130 -1,548 1,265 226,420 2,190,927 3,781 2,948 -2,216 -1,619 1,324 226,349 2,190,986 CONFIDENTIAL 3,805 2,964 -2,232 -1,632 1,335 226,336 2,190,997 3,889 3,021 -2,289 -1,680 1,375 226,288 2,191,037 3,982 3,084 4,077 3,152 4,171 3,221 4,266 3,294 4,361 3,369 4,408 3,407 4,488 3,472 4,550 3,523 4,645 3,600 4,740 3,677 4,834 3,753 4,929 3,831 5,023 3,908 5,118 3,985 5,213 4,064 5,308 4,143 5,402 4,222 5,497 4,302 5,592 4,381 5,686 4,461 5,781 4,541 5,876 4,621 5,971 4,702 6,065 4,782 6,160 4,864 6,255 4,946 6,349 5,028 6,444 5,110 6,539 5,194 6,634 5,277 6,760 5,389 6,886 5,502 7,013 5,616 7,139 5,730 7,266 5,846 7,392 5,962 7,518 6,079 7,645 6,197 7,771 6,315 7,865 6,403 7,960 6,492 8,086 6,611 8,212 6,731 8,362 6,874 8,420 6,929 -2,352 -1,733 1,418 226,235 2,~80 -2,420 -1,785 1,460 226,183 2,~2 -2,489 -1,835 1,497 226,133 2,191,159 -2,562 -1,885 1,533 226,083 2,191,195 -2,637 -1,931 1,569 226,037 2,191,231 -2,675 -1,952 1,586 226,016 2,191,248 -2,740 -1,989 1,615 225,979 2,191,277 -2,791 -2,017 1,637 225,951 2,191,299 -2,868 -2,060 1,672 225,908 2,191,334 -2,945 -2,104 1,706 225,864 2,191,368 -3,021 -2,147 1,740 225,821 2,191,402 -3,099 -2,190 1,774 225,778 2,191,436 -3,176 -2,233 1,808 225,735 2,191,470 -3,253 -2,276 1,841 225,692 2,191,503 -3,332 -2,317 1,875 225,651 2,191,537 -3,411 -2,357 1,909 225,611 2,191,571 -3,490 -2,396 1,943 225,572 2,191,605 -3,570 -2,436 1,976 225,532 2,191,638 -3,649 -2,475 2,009 225,493 2,191,671 -3,729 -2,514 2,042 225,454 2,191,704 -3,809 -2,553 2,074 225,415 2,191,736 -3,889 -2,592 2,107 225,376 2,191,769 -3,970 -2,630 2,139 225,338 2,191,801 -4,050 -2,668 2,170 225,300 2,191,832 -4,132 -2,706 2,200 225,262 2,191,862 -4,214 -2,744 2,229 225,224 2,191,891 -4,296 -2,780 2,258 225,188 2,191,920 -4,378 -2,816 2,288 225,152 2,191,950 -4,462 -2,852 2,316 225,116 2,191,978 -4,545 -2,888 2,344 225,080 2,192,006 -4,657 -2,934 2,380 225,034 2,192,042 -4,770 -2,979 2,414 224,989 2,192,076 -4,884 -3,022 2,448 224,946 2,192,110 -4,998 -3,063 2,482 224,905 2,192,144 -5,114 -3,104 2,513 224,864 2,192,175 -5,230 -3,143 2,544 224,825 2,192,206 -5,347 -3,180 2,575 224,788 2,192,237 -5,465 -3,216 2,604 224,752 2,192,266 -5,583 -3,251 2,632 224,717 2,192,294 -5,671 -3,276 2,653 224,692 2,192,315 -5,760 -3,300 2,673 224,668 2,192,335 -5,879 -3,332 2,700 224,636 2,192,362 -5,999 -3,362 2,725 224,606 2,192,387 -6,142 -3,397 2,756 224,571 2,192,418 -6,197 -3,410 2,767 224,558 2,192,429 . CONFIDENTIAL >Information >Well >Directional Surveys >R.ata (MD, Inc, Az.) Select Well: HV10 _ . Report Name Well Field API KB Date Created Directional Survey HV10 UNKNOWN 502312002800 732.5 1/19/2005 MD Inclination Azimuth (ft} 0 0 0 176 0.59 320.92 238 0.67 328.53 238 0.67 328.53 300 1.57 319.72 300 1.57 319.72 361 2.68 316.08 361 2.68 316.08 423 3.91 316.42 423 3.91 316.42 485 6.34 313.07 485 6.34 313.07 547 8.89 309.2 547 8.89 309.2 608 11.46 306.68 608 11.46 306.68 671 13.85 308.49 671 13.85 308.49 733 15.75 310.46 733 15.75 310.46 796 16.96 310.4 796 16.96 310.4 859 18.49 308.66 859 18.49 308.66 890 19.17 307.72 890 19.17 307.72 1037 26.62 305.74 1037 26.62 305.74 1131 28.4 305.11 1131 28.4 305.11 1226 32.2 306.62 MD Inclination Azimuth (ft) 1226 32.2 306.62 1289 33.56 306.81 1289 33.56 306.81 1352 34.88 306.71 1352 34.88 306.71 1415 36.8 308.07 1415 36.8 308.07 1478 39.38 309.13 1478 39.38 309.13 1541 42.13 308.61 1541 42.13 308.61 1604 44 308.67 1604 44 308.67 1667 45.74 CONFIDENTIAL 307.99 1667 45.74 307.99 1730 46.65 308.27 1730 . 46.65 . 308.27 1794 46.4 308.32 1794 46.4 308.32 1857 47.78 308.1 1857 47.78 308.1 1920 49.17 308.56 1920 49.17 308.56 2046 48.68 308.25 2046 48.68 308.25 2172 48.52 307.45 2172 48.52 307.45 2299 48.51 307.48 2299 48.51 307.48 2425 48.11 307.33 2425 48.11 307.33 2551 47.74 307.07 2551 47.74 307.07 2678 47.76 306.84 2678 47.76 306.84 MD Inclination Azim uth (ft) 2771 47.26 308.12 2771 47.26 308.12 2898 47.28 308.69 2898 47.28 308.69 3024 47.22 308.4 3024 47.22 308.4 3150 47.1 308.25 3150 47.1 308.25 3276 46.94 307.68 3276 46.94 307.68 3403 47.21 308.42 3403 47.21 308.42 3529 47.11 308.51 3529 47.11 308.51 3655 47.01 308.64 3655 47.01 308.64 3781 47.19 308.79 3781 47.19 308.79 3805 46.99 308.72 3805 46.99 308.72 3889 47.69 308.19 3889 47.69 308.19 3982 46.31 307.66 3982 46.31 307.66 4077 42.99 307.14 4077 42.99 307.14 4171 41.64 303.6 4171 41.64 303.6 4266 38.76 305.89 4266 38.76 305.89 4361 36.35 306.98 4361 36.35 306.98 4408 35.52 306.98 4408 35.52 rONFfDENTfAL 306.98 4488 35.28 307.5 MD . Inclination . Azimuth (ft} 4488 35.28 307.5 4550 35.48 307.26 4550 35.48 307.26 4645 36.05 307.26 4645 36.05 307.26 4740 35.7 306.97 4740 35.7 306.97 4834 35.5 306.57 4834 35.5 306.57 4929 35.38 307.72 4929 35.38 307.72 5023 35.08 306.33 5023 35.08 306.33 5118 34.97 306.54 5118 34.97 306.54 5213 33.61 309.78 5213 33.61 309.78 5308 33.4 308.53 5308 33.4 308.53 5402 33.04 309.47 5402 33.04 309.47 5497 32.7 308.04 5497 32.7 308.04 5592 32.79 309.05 5592 32.79 309.05 5686 32.65 309.55 5686 32.65 309.55 5781 32.16 307.51 5781 32.16 307.51 5876 32.03 309.19 5876 32.03 309.19 5971 31.46 308.61 5971 31.46 308.61 6065 31.1 306.94 6065 31.1 306.94 MD Inclination Azimuth (ft) 6160 30.74 306.74 6160 30.74 306.74 6255 29.79 307.05 6255 29.79 307.05 6349 29.58 307.61 6349 29.58 307.61 6444 29.26 307.6 6444 29.26 307.6 6539 28.54 306.84 6539 28.54 306.84 6634 28.06 306.6 6634 28.06 306.6 6760 27.02 306.08 6760 27.02 306.08 6886 26.21 306.56 6886 26.21 CONFIDENTIAL 306.56 7013 25.26 307.99 7013 . 25.26 . 307.99 7139 24.53 306.99 7139 24.53 306.99 7266 23.57 306.28 7266 23.57 306.28 7392 22.66 307.75 7392 22.66 307.75 7518 22.15 308.56 7518 22.15 308.56 7645 21.09 307.37 7645 21.09 307.37 7771 20.17 307.86 7771 20.17 307.78 7865 20.04 308.98 7865 20.04 308.98 7960 19.53 308.29 7960 19.53 308.29 8086 18.79 308.5 MD Inclination Azimuth (ft) 8086 18.79 308.5 8212 18.01 309.71 8212 18.01 309.71 8362 17.42 310.48 8362 17.42 310.48 8420 17.42 310.48 8420 17.42 310.48 End of Report CONFIDENTIAL . . Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCALi) Debra Oudean G & G Technician Date: December 15,2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#IOO Anchorage, AK 99501 HAPPY VALLEY 10&11 \tV ~' 1 ':TLOGic ';[\INTERVAL~;..;'·>h' ' SCALE DATE' ~LOGGED;' LINE FILM CD".; NOTES ¡HAPPY V ALLEY -10I~g~~~~~~SN RECORD 2.5 HSD 15 INCH '11/19/2oa4f844'82461 1r 1-~ jHAPPYYALLEY.10 IpER~()RATIO~RECORD 2.52506PJ 6S~Ff5iNCHI11/1 0/20041821.6.8236 [1Di1 ¡HAPPY VALLEY·10 ISLlM CEME~TMAPPING TOOL sINCH'11/1/2004þ520.8312 ~I ] IHAPPY VALLEY -1 0 ~g~~INABLE MAGNETIC RESONANCE r~~HI10/12/200413900-7846'nT I HAPPY VALLEY-10 DIPOLE SHEAR SONIC TOOL I:~~H ;110/12120041200.7882 .~ 0 COMB6NDED aNI HAPPY VALLEY -1 0 ~~J~~I~~ ~:~~~:~~~~~IC TOOL I~~H 10/12/2004 200'~882 1.. 1 0 J IHAPPYVALLEY~11 ~~~RO:~N~6~~~~SM~ARRAY DIPOLEI~~H 11/9/2oot507.6865· .[fOr I HAPPY V ALLEY ·11 ~~~RO:~N~6~~~~S;6ARRA Y DIPOLE .I¡~~H . .11119/200414507 .6865m 0 COMBINED ON I HAPPY VALLEY ·11 g:~gt~ ~~~~~ ~ODNIC TOOL P&S UPPERI~~HI11/9/200414507 ·6865 .~ 0 CD I ¡HAPPYVALLEY'11 g:~gt~~~~~~~~~ICTOOLP&SUPPER~~HI11/9/200414507-6865 .. 1. 0 0~1 ¡IHAPPY VA. LLEY'.11 PRESSURE 1 TEMPERATURE SURVEY' [2iNCH'111I97200410-45. 10 11ToT1".· . CEMENT TOP IDENTIFICATION I I 1 I I I· IHAPPY VALLEY.11CMLSONIC QUADC()MBO MD . 12 INCH 11/11/2004 4506~.4470 1 COMBINED ON I IH~~~!,~~~~~Y.:1LI~~~?_~NIC~A_D c~~§g!,,~, 1?I~c~11_!l1~(2~~I~~0~-~~~ 0 . ____~~. .... ___J ning one copy of this transmittal or FAX to (907) 263-7828. Date: . . Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCAL Debra Oudean G & G Technician Date: December 6, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 HAPPY VALLEY 10 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: "7 JJ.4... ~~t L( ,'1 1\ . . v( ;/\ (://"'1 0\0 o ü z o o w z CO ~ o ü .-.¡ 1--; -e, . . FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA. OILAlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Phil Krueger Drilling Manager Union Oil Company of California (Unocal) P.O. Box 196247 Anchorage, Alaska 99519 Re: Happy Valley #10 Union Oil Company of California (Unocal) Permit No: 204-186 Surface Location: 1118' FSL, 1296' FEL, SEC. 22, T2S, R13W, SM Bottomhole Location: 3953' FSL, 4925' FEL, SEC. 22, T2S, R13W, SM Dear Mr. Krueger: Enclosed is the approved application for permit to drill the above referenced development well. The permit is approved subject to full compliance with 20 AAC 25.055 and to UNOCAL's submission to the Commission of an application for pool rules for the Deep Creek Unit before November 15, 2004. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Unocal assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commi 10 to witness any required test. Contact the Commission's petroleum field inspector at (907 659- 7 (pager). BY ORDER ?!J"THE COMMISSION DATED this~ day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · Unocal corporat. P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe Thursday, September 23, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill (Form 10-401) Happy Valley #10 RECEIVED SEP 2 3 2004 Alaska Oil & Gas Cons. CíJmrn.¡s¡;ìoo Anchorag.e Attn: Commission Chair John Norman Dear Commissioner Norman, Attached for your approval is an application for permit to drill (Form 10-401) for the Happy Valley #10 Well. Unocal respectfully requests a waiver of the requirement for a diverter on the 12-1/4" / surface hole as allowed under AOGCC Regulation 20 AAC 25.035 (h) (2). Please refer to attached supporting documentation. Unocal respectfully requests a waiver of the requirement for an alternate BOPE test frequency as allowed under AOGCC Regulation 20 AAC 25.?~9ì(h) (1). The anticipated spud date is approximately SePtember&+~<W04. If you have any questions please contact myself at 263-7628, or Mr. Ste~~~be @ 263-7637. Sincerely, Vlþ)J~ / Phil Krueger Drilling Manager SSL/s Enclosure r'\ ¡ ¡ 1 a. Type of Work: Drill ~ Redrill U Re-entry D \IJ GA- q fl4/Z(J01 . STATE OF ALASKA . ASKA Oil AND GAS CONSERVATION MISSION RECEIVED PERMIT TO DRILL 2 3 2004 20 AAC 25.005 SEP 1 b. Current Well Class: Exploratory D Development Oil .W ~Itimft~ D Stratigraphic Test D Service D AI"Idi)jIr&,Go~~O~. t:sVrWlè"fone D 5. Bond: Blanket l.:J Single Well U MCDDJRIþme and Number: Bond No. 5534278 Happy Valley #10 6. Proposed Depth: 12. Field/Pool(s): MD: 8578 TVD: 7000 Beluga / Upper Tyonek 7. Property Designation: C-061590 8. Land Use Permit: 2. Operator Name: Union Oil Company of California (Unocal) 3. Address: PO Box 196247, Anchorage, Alaska, 99519 4a. Location of Well (Governmental Section): Surface: 1118' FSL, 1296' FEL, Sect 22, T2S, R13W, SM Top of Productive Horizon: 2574' FSL, 3159' FEL, Sect 22, T2S, R13W, SM Total Depth: 3953' FSL, 4925' FEL, Sect 22, T2S, R13W, SM 4b. Location of Well (State Base Plane Coordinates): Surface:x- 227968 y- 2189662 Zone- 16. Deviated wells: Kickoff depth: Maximum Hole Angle: NA 13. Approximate Spud Date: 9/27/2004 14. Distance to Nearest 3040 Property: 355 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 16.5 feet Within Pool: 1586 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3129 Surface: 1980/' Setting Depth Quantity of Cement c.f. or sacks Top Bottom MD TVD 9. Acres in Property: 4 350 feet 48 degrees 18. Casing Program: Size Casing 13-3/8 12.25 9.625 8.5 7 6.125 3.5 Specifications Hole Weight Grade 72 K-55 40 L-80 26 L-80 9.3 L-80 Coupling Weld Butt-ABM Butt-ABM Butt-ABM Length 68 950 3864 4978 MD TVD 0 0 0 0 0 0 3600 2824 68 950 3864 8578 (including stage data) 68 Driven 937 80 bbls (50 % excess) , 3000 82 bbls (20% excess) ~ 7000 147 bbls (30% excess) " NA 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Length Size Cement Volume MD TVD Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Property Plat 0 Diverter Sketch D Seabed Report D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Time v. Depth Plot ~ Shallow Hazard Analysis U Drilling Fluid Program 0 20 AAC 25.050 requirements D Date Contact Printed Name Phil Krueger Title Drilling Manager Signature ~ -./¿~, .::> Phone 263-7628 j/ / / Commission Use Only Permit to Drill I API Number: Permit Approval Number:.2 0 <;1- /!?þ 50- :2..3/,.. :¿oo:¿, g- Date: .j/é)t.¡/O tf Conditions of approval: T.e ç, t. ~E to .~ ç' 00 p ç, l , . Sampl require Yes D N:J Mud log required Yes D No ~ D ü§/. H oge~~ulf e me¡;¡sur~s. . Ye.. s D No Di.r~ctional. s¡.¡rvey .reqUire. d.. Yes ~ No D Other' I ~ 0 . O~ ) { ¿} J ck I.f e.r t €.y' r<'£ u..{ N .e'IA-f ¡ .. ¡..U tu 1/ l'd. i , f< 20/~." rLv."'M~\U\, ..It""',,-,,- ie' gopE ¡."<ty~. ~61.K"ß1'1 s '4')pYove~~..¿ Approved . 7 - y ~/'- -. ,_ ,.....,.TI;i£; CPfI/\MIj5SION Date: F / ~ /' ott- ~ Form ~1 ~d 12/2003 U \< lJ \ \\1 f-\ L I SUb~it inDuplicate Date 9/23/2004 See cover letter for other requirements. . . WAIVER REQUEST Unocal respectfully requests a waiver to; (1.) AOGCC regulations 20 AAC 25.035 (C) WAIVER #1 : Unocal request permission to drill the 12-1/4" suñace hole to a depth of +/- 950 MD/937'VD' without a diverter. AOGCC regulation 20 AAC 25.035 (h) / (2) stipulates: (h) ltUpon request f the operator, the commission will, in its discretion, approve a variance ...... (2) from the diverter system requirements in (C) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary." Based on our experience drilling 12 %" suñace holes in Happy Valley #1-9 it has been proven conclusively that no shallow gas hazards exist beneath this pad to a depth of at least 2654' VD. The 12-1/4" suñace hole for Happy Valley #10 will be drilled from the same pad as Happy Valley Wells #1 through #9. For the purpose of basic risk mitigation, Unocal will utilize a gel/native spud mud which is expected to weigh approximately 9.2 ppg when drilling at the planned suñace hole TD of 950', to eliminate the risk of a shallow water flow. . . Happy Valley #10 Bullet Procedure Install cellar for containment w/13-3/S" conductor string Prepare pad & install liner, tankage & berms Turnkey rig move from Red Pad Rig Acceptance. Hold pre-spud & HES meetings. Mix mud, RU pipe handling equipment, etc. P/U portion of BHA Clean out conductor & drill out shoe PU remainder of BHA & drill string Drill 12-1/4" hole from 0' to 950' MD, 937'VD / Circ Clean & pump carbide indicator Pump out to BHA & POH LID BHA Clear rig floor & RU to run 9-5/S" casing RIH with 9-5/S" casing Land casing, M/U head, establish circulation RU to cement & conduct safety meeting Pressure test lines & cement 9-5/S" casing RD casing running equipment ./! NU & test MBS wellhead 6 j ./' NU BOPE, choke/kill lines & test to 25 .3500"PSi PU & RIH S-1/2" BHA. .../ Drill out & perform LOT Drill S-1/2" hole from: 950' to: 3S64' MD /3000' VD Circ clean & pump carbide indicator Pump out to BHA & POH LID BHA Clean rig floor & RU to run 7" csg RIH w/7" surface casing Land casing, MlU head, establish circulation RU to cement & conduct safety meeting Pressure test lines & cement 7" casing RD casing running equipment RIH w/6-1/S" steerable BHA Drill out & perform LOT Drill 6 1/S" hole from: 3,S64' MD to: 4,450' MD /-3,450' VD Circulate sweep, SIT, check for swabbing, etc. POH (assumes pump out required due to swab) Rack Back BHA & PU 90' of 6-1/S" Core Barrel. TIH to 4450. . Cut 90' 6-1/S" core -4450' to 4540'. / TOH & Recover Core barrels. PU & RIH 6-1/S" Drilling BHA to 4540'. Drill 6 1/S" hole from: 4,540' MD to: 5,9S0' MD /-4,750' VD Circulate sweep, SIT, check for swabbing, etc. POH (assumes pump out required due to swab) Rack Back BHA & PU 90' of 6-1/S" Core Barrel. TlH to 59S0. / Cut 90' 6-1/S" core -5980' to 6070'. TOH & Recover Core barrels. PU & RIH 6-1/S" Drilling BHA to 6070'. Drill 6 1/S" hole from: 6,070' MD to: S,130' MD /-6,700' VD Circulate sweep, SIT, check for swabbing, etc. POH (assumes pump out required due to swab) Rack Back BHA & PU 90' of 6-1/S" Core B"rrel. TlHtoS130. / Cut 90' 6-1/S" core -8130' to 8220'. TOH & Recover Core barrels. LD Coring E;ZUiP. nt PU & RIH 6-1/S" Drilling BHA to S220'. / Drill61/S" hole from: S,220' MDto: ,57MD/-7,OOO'VD Circulate sweep, SIT, check for swabbing, ;" POH & LD Drilling BHA RU SWS E-line unit, run PEX + Sonic /" RUN CMR RD Logging Unit RIH, C&C, POOH & LID D~ess 3,800' RU & run 3 1/2" Liner / RIH w/ Liner on DP. Circulate, reciprocate & conduct safety meeting RU, test lines, pump cement, Set hanger & Packer, & check floats Circulate Well Clean. Test Packer. Circulate to Complétion Brine POOH LD DP. Prep to run tubing. MU & RIH 3-1/2" Completion String Space out & Land Seals / Test Tubing, Liner & annulus. ND BOPE NU & test tree Clean rig & pits, release rig Location: X=227,967.990 E, Y=2,189,662.286 N Lat: 59° 59' 07.642" N, Long: 151° 29' 07.668" W 1118' FSL, 1296' FEL, Sec22, T2S, R13W, S.M. RKB = 17' AGL GL = 716' AMSL RKB elevation = 733' AMSL 13·38" 72 ppf butt 12-1/4" hole (drilled w/out dìverter, AOGCC waiver requested, confirm approval) 9.2 ppg KCL- WBM Cement to surface req'd w/350' 15.8 ppg G tail & 600' 12.8 ppg extended G lead Planned TD 8,578' MD 17,000' VD Static BHT = 36.8°F + (0.0136 x TVD) Job Template #1 REVISED: 09/22/04 DRAWN BY: SSL . . S. Kenai Gas project Happy Valley #10 7" SHOE DESIGN SUMMARY & SKETCH UtlOCAL 9-5/S" shoe 920 ft BML ( 937 ft TVD) S-1/2" Hole mdb/01decOO METHOD 2: RT - MSL = 17 ft WD = 0 ft with 0.447 PSI/FT Gradient \ I \ I \ I \ I \ 1 \ 1 \ 1 \ I \ I - DESIGN DOWN: MW = 9 PPG Pform = 9 PPG EMW KT = 15 BBlS at 0 PPG FG = 0.8 PSI/FT Gas Gradient = 0.02 PSI/FT Drill Pipe = 4 INCH 9-5/S" shoe The shallowest 7 " shoe depth = 786 ft BML or 803 ft TVD .. - S-1/2" Hole TD = 2,983 ft BML or 3,000 ft TVD METHOD 1: \ I \ I \ I \ 1 \ ¡DESIGN UP: I MW = 9 PPG \ Pform = 9 PPG EMW I KT = 15 BBlS at 0 PPG \ FG = 0.8 PSI/FT 1 Gas Gradient = 0.05 PSI/FT \ Drill Pipe = 4 INCH I \ I \ I - . . GENERAL INPUT DATA Field Well Name RT-MSL Water Depth Sea Water Gradient Casing Size to be Designed Hole Size Drilled for This Casin S. Kenai Gas project Happy Valley #10 17ft Oft 0.447 psi/ft 7 inch 8-1/2 inch DESIGN METHOD 1: From TD up to find the shallowest allowable shoe depth Hole Size Below the Shoe Next Section Total Vertical Depth Next Section Total Vertical Depth Next Section Gas Gradient (first approximation: 0.021) Kick Intensity cannot be less than 0 ppg Mud Weight Estimated Formation Pressure at Next Section TD Fracture Gradient Kick Tolerance Drill Pi e Outside Diameter 8-1/2 inch 3,000 ft TVD RKB 2,983 ft TVD BML 0.050 psilft 0.0 PPG 9.0 PPG 9.0 PPG EMW 0.80 psi/ft 15.0 bbl 4 inch ICalculation results acceptable. Minimum shoe depth = 803 ft TVD RKB 1142 DESIGN METHOD 2: From upper casing shoe down to find the deepest hole which can be drilled without fracturing the upper casing shoe Upper Casing Size Upper Casing Shoe Depth Upper Casing Shoe Depth Upper Gas Gradient (first approximation: 0.007) Hole Size below the Upper Casing Shoe Kick Intensity cannot be less than 0 ppg Mud Weight Estimated Formation Pressure Fracture Gradient Kick Tolerance Drill Pipe Outside Diameter 9-5/8 inch 937 ft TVD RKB 920 ft TVD BML 0.020 silft 8-1/2 inch 0.0 PPG 9.0 PPG 9.0 PPG EMW 0.80 psi/ft 15.0 bbl 4 inch Calculation results acceptable. Maximum shoe depth = 3,846 ft TVD RKB mdb/01decOO 2788 . s. Kenai Gas project Happy Valley #10 3-1/2" SHOE DESIGN SUMMARY & SKETCH 7 "shoe 2,898 ft BML (2.915 ft TVD) 6-1/8" Hole mdb/01decOO METHOD 2: RT - MSL = 17 ft we = 0 ft with 0.447 PSI/FT Gradient \ I \ I \ I \ I \ I \ I \ I \ I \ I - DESIGN DOWN: MW = 9.3 PPG Pform = 9.8 PPG EMW KT = 15 BBLS at 0.5 PPG FG = 0.74 PSI/FT Gas Gradient = 0.02 PSI/FT Drill Pipe = 4 INCH ! . 7 " shoe The shallowest 3-1/2" shoe depth = 2,814 ft BML or 2,831 ft TVD .. - 6-1/8" Hole TD = 6,983 ft BML or 7,000 ft TVD METHOD 1: L. ¡DESIGN UP: MW = 9.3 PPG Pform = 9.8 PPG EMW KT = 15 BBLS at 0.5 PPG FG = 0.74 PSI/FT Gas Gradient = 0.05 PSI/FT Drill Pipe = 4 INCH . . GENERAL INPUT DATA Field Well Name RT-MSL Water Depth Sea Water Gradient Casing Size to be Designed Hole Size Drilled for This Casin S. Kenai Gas project Happy Valley #10 17 ft Oft 0.447 psi/ft 3-1/2 inch 6-1/8 inch DESIGN METHOD 1: From TD up to find the shallowest allowable shoe depth Hole Size Below the Shoe Next Section Total Vertical Depth Next Section Total Vertical Depth Next Section Gas Gradient (first approximation: 0.052) Kick Intensity (Swab kick = 0.0 ppg intensity) Mud Weight Estimated Formation Pressure at Next Section TD Fracture Gradient Kick Tolerance Drill Pi e Outside Diameter 6-1/8 inch 7,000 ft TVD RKB 6,983 ft TVD BML 0.050 psi/ft 0.5 PPG 9.3 PPG 9.8 PPG EMW 0.74 psi/ft 15.0 bbl 4 inch ICalculation results acceptable. Minimum shoe depth = 2,831 ft TVD RKB 1142 DESIGN METHOD 2: From upper casing shoe down to find the deepest hole which can be drilled without fracturing the upper casing shoe Upper Casing Size Upper Casing Shoe Depth Upper Casing Shoe Depth Upper Gas Gradient (first approximation: 0.022) Hole Size below the Upper Casing Shoe Kick Intensity (Swab kick = 0.0 ppg intensity) Mud Weight Estimated Formation Pressure Fracture Gradient Kick Tolerance Drill Pipe Outside Diameter 7 inch 2,915 ft TVD RKB 2,898 ft TVD BML 0.020 si/ft 6-1/8 inch 0.5 PPG 9.3 PPG 9.8 PPG EMW 0.74 psi/ft 15.0 bbl 4 inch Calculation results acceptable. Maximum shoe depth = 7,009 ft TVD RKB mdb/01decOO 7132 . . UNDCALe Maximum Anticipated Surface Pressure Calculation Happy Valley Well #10 Kenai Peninsula, Alaska Assumptions: 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a OG~Si/ft gradient from surface to planned total depth at 7,000' VD BRT. 2. The M.A.S.P. during drilling operations will be governed by the 7" shoe frac gradient, and is calculated based on a full column of gas between the 7" shoe and the surface. The shoes for HV #10 will be at the same depth as the shoes in HV well #8 & #9 thus the nearby LOT data from approximately 2936' VO is useful for relatively accurate kick tolerance & MASP calculations. 3. The M.A.S.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TO & the surface. M.A.5.P. During Production Life: ,// Max. pore pressure at T.O. = 7,000 ' VO x ob' = 3129 psi MAS.P. (tbg leak at surface) = 3129 psi - (0.096 psi/ft * 7,000 ft) = = 2457 psi M.A.S.P. While Drilling 6-1/8" hole at 8,578' MD: Max. Est. Frac pressure at 7" shoe = 3000 ft. x 0.74 psi/ft* = = 2220 psi MAS.P. during drilling = 2220 psi - (.08 psi/ft x 3000 ft.) = = 1980 psi / M.A.S.P. While Drilling 8-1/2" hole at 3,864' MD: Max. Est. Frac pressure at 9-5/8" shoe = 937 ft. x 1 psi/ft** = = 937 psi MAS.P. during drilling = 937 psi - (.08 psi/ft x 937 ft.) = = 862 psi ** highest observed FG at +1-1032' VO in Happy Valley area to date Calculation & Casing Design Factors UNOCAL6) Happy Valley Well #10 Kenai Peninsula, Alaska WELL: Happy Valley #10 FIELD: South Kenai Gas DATE: 22-Sep-04 DESIGN BY: Steven Lambe Sect. 1 121/4" hole MUD WT. 9.2 PPG MASP=862 psi" Sect. 2 8 1/2" hole MUD WT. 9.2 PPG MASP= 1,980 psi Sect. 3 6-1/8" hole MUD WT. 9.4 PPG MASP= 2,457 psi Production Mode TENSION MINIMUM COLLAPSE COLLAPSE WEIGHT TOP OF STRENGTH / PRESS @ RESIST. / DESCRIPTION W/O BF SECTION TENSION WORST CASE BOTTOM wlo TENSION WORST CASE SECTION CASING BOTTOM TOP lENGTH WT. GRADE THREAD lBS ~ 1000 lBS SF TENSION PSI' PSI SF COlL. 1 9-5/8" 950 0 950 40 K-55 BTC 38,000 38,000 1300 34.21 412 1,950 4.73 TVD 937 0 2 7" 3,864 0 3864 26 L-80 BTC-mod 100,464 100,464 979 9.74 1,320 3,090 2.34 TVD 3,000 0 3 31/2" 8,578 3600 4978 9.2 l-80 IBT-mod 45,798 45,798 207 4.52 3,080 10,530 3.42 TVD 7,000 2824 , Collapse pressure is calculated; Normal Pressure Fluid Gradient for extemal stress (.44 psilft) and the casing evacuated for the intemal stress (0 psi/ft) " See attached sheet for calculation of MASP Note: All wellhead components are rated to 5000 psi working pressure, with the exception of the X-mas tree and tree adapter spool, which are rated to 6500 psi working pressure. . MINIMUM .-/ MASP YIELD WORST CASE PSI" PSI SF BURST 866 3,450 3.98 ("3.7j1J 5,750 1.55 '-~ 3,717 10,160 2.73 . . . Property arids and formulas for Happv Vallev #10 Well Specifics: Casing Program MD TVD Footaae 12 ~" hole ( 9 5/8" 950' 937' 950' casinq) 8 %" hole (7" casing) 3864' 3000' 2914' 6 1/8" hole (3.5" casinq) 8578' 7000' 4714' Surface Hole Recommendations Mud Type: 6%KCI, EZ Mud P ropertles: Densitv Viscosity Plastic Viscosity Yield Point APIFL Il!:! o - 950' 9.0-9.2 60 - 85 6 -16 35 - 45 <8 8.5-9.0 System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 20 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.5 -2 ppb (as required 35-45 YP) PACL 1 ppb EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 ppb (add as the well spuds) Intermediate Hole Recommendations Mud Type: 6%KCI, EZ Mud P ropertles: Densitv Viscosity Plastic Viscosity Yield Point API FL Il!:! 950' - 2500' 9.0-9.2 40-53 6 - 15 15 - 25 <8 8.5-9.0 2500' - 3846' 9.1 -9.3 40-50 6 - 15 15 - 25 <8 8.5-9.0 System Formulation: Product Water KCI KOH Barazan D Dextrid EZ Mud DP Aldacide G Baracor 700 Barascav D 6%KCI, EZ Mud Concentration 0.905 bbl 19.8 ppb (30K chlorides) 0.2 ppb (9 pH) 1.25 ppb (as required 35 YP) 1-2 ppb 0.75 ppb 0.1 ppb 1 ppb 0.5 b maintain er dilution rate . Production Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: 3846 - 8578' . Plastic Viscosity 6 - 15 Yield Point 15 - 25 System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 19.8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 35 YP) Dextrid 1-2 ppb PAC L 1 ppb EZ Mud DP 0.75 ppb AldaCÎde G 0.1 ppb Baracor 700 1 ppb Barascav D 0.5 b maintain er dilution rate APIFL <5 Q!i 8.5-9.0 .. Ground Level / 11" 5M MBS / Wellhead z-. 9-5/8" x 40# Surface ICementedi ¡q 13·3/8" x 12# ------I>o Conductor (driveni 2" thick base Dlate 10'0" -----~ o 5 10 15 Time (Days) 20 25 HV #10 AFE .. V " ....... II... 0-. \v..........._.. ..V/ 30 ~__4-~V., ._............ ..... - Created by: Planner :.._ 1 Date plotted: 22-Sep-2004 Plot reference is HV#10 Ver 1. Refwellpath is HV#10 Ver 1. Coordinates are in feet reference HV#10. True Vertical Depths are reference Rig O.~_: . .atum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 732.50 ft. Plot North is aligned to TRUE North. ----,------- -400 ¢:: 0 0 0 N II E 400 t,,) Q) (ij 800 0 U) 1200 1600 ~ 2000 2400 - - Q) Q) :t:. 2800 = a. Q) 3200 C iã 0 3600 :;:J ~ ~ 4000 Q) ::J ~ .... 4400 I V 4800 5200 ~ 5600 6000 .. 6400 I 6800 1 7200 7600 I I K~ ¡ 7.00 \ \ 14.00 DLS: 3.50 deg/100ft ¿ \1:> 9 518" Casing \ 28.00 35.00 \" 42.00 ~End of Build ~ ~~ End of Hold \~ 7" Casing 44~~0 ~ Beluga 40 ~- 37.44 \ \ 33.44 \ , End of Drop \ \ 3112" Uo.. ~_ TO . I L~.tio", ~~o~~A~. UNOCAL ::::: I HV#10 ~ Field: South Kenai Gas Field Well: Installation: Happy Valley Wellbore: Seale 1 em = 250 ft East (feet) -> -4500 -3000 -1000 -500 500 o -2500 -2000 -1500 -4000 -3500 3500 3000 2500 2000 ^ I Z 1500 0 ;::s. :r - .... 1000 ~ - - 500 en 0 '" 0 r0- o 3 " -500 '" '" 0 ;:: (~ 3112" Uo" ~'~" ~~ HV#10 - Beluga 40 - 9/9/04 ( "~ 7" Casing \,~ " "~~.~ 9 5/8" Casing ~ ~ INTEQ ~- WELL PROFILE DATA ~. Point MD Inc JUI TVD North East deg/1 DOlt V. Sect Tie on 0.00 0.00 308.00 0.00 0.00 0.00 0.00 0.00 KüP 350,00 0.00 308.00 350,00 0.00 0.00 0.00 0.00 End of Build 11721.43 48.00 308.00 1566.55 333.47 -426.82 3.50 541.64 I End of Hold 3863.68 48.00 308.00 2999.99 1313.60 -1681.34 0.00 2133.65 Target HV#10 - Beluga 4191.78 41.44 308.00 3233.00 1455.66 -1863.16 2.00 2364.38 End of Drop 4763.68 30.00 308.00 3696.55 1660.88 ·2125.82 2.00 2697.71 T.O. & TargetHV#10- T 8518.18 30.00 308.00 7000.00 2835.10 ~362B. 76 0.00 4604.96 -400 -0 400 Scale 1 cm = 200 ft / I -----¡-¡ I ---,--¡---,---,~ 800 1200 1600 2000 2400 2800 3200 3600 4000 Vertical Section (feet) -> Azimuth 308.00 with reference 0.00 N, 0.00 E from HV#10 5200 4400 4800 · UNOCAL- Created by: Planner Date plotted: 10-Sep-2004 Plot reference is HV#10 Var 1. Ref wellpath is HV#10 Var 1. Coordinates are in feet reference HV#10. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 732.50 ft. Plot North is aligned to TRUE North. Location: Kenai Peninsula, Alaska Slot: HV#10 Field: South Kenai Gas Field Well: HV#10 Installation: Happy Valley Wellbore: HV#10 Ver 1 r... BAKER HUGHES INTEQ TRUE NORTH 350 o 340 700 600.. 16 '·,.400 "',300 20'..200 200 .200 '-. 30 ,600 , 240 330 320 ,,700 ... 40 '. 800 310 , 50 , ,,900 300 60~ 290 70 280 80 270 2 0 90 260 100 250 110 120 230 130 220 140 2 0 , 15èJ.1200 210 200 160 190 180 170 \4,300 "\<:ì Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well . . UNoea... UNOCAL ,HV#10 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 1 Wellbore: HV#10 Ver 1 Wellpath: HV#10 Ver 1 Date Printed: 22-Sep-2004 INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Oatum #1 732.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 308.00 degrees Bottom hole distance is 4604.96 Feet on azimuth 308.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . U.DC."'. UNOCAL ,HV#10 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Wellbore: HV#10 Ver 1 Wellpath: HV#10 Ver 1 Date Printed: 22-Sep-2004 INTEQ 0.00 0.00 308.00 0.00 O.OON O.OOE 0.00 0.00 227967.99 2189662.30 100.00 0.00 308.00 100.00 O.OON O.OOE 0.00 0.00 227967.99 2189662.30 _200.00 0.00 30M-º----. __ 200.0.(L O.OON O.OOE 0.00 0.00 227967.99 2189662.30 300.00 0.00 308.00 300.00 O.OON O.OOE 0.00 0.00 227967.99 2189662.30 350.00 0.00 308.00 350.00 O.OON O.OOE 0.00 0.00 227967.99 2189662.30 450.00 3.50 308.00 449.94 1.88N 2.41W 3.50 3.05 227965.63 2189664.23 550.00 7.00 308.00 549.50 7.51N 9.62W 3.50 12.20 227958.55 2189670.03 650.00 10.50 308.00 648.32 16.88N 21.60W 3.50 27.41 227946.77 2189679.66 750.00 14.00 308.00 746.03 29.94N 38.32W 3.50 48.63 227930.35 _ 2189693.0~~ 850.00 17.50 308.00 842.26 46.65N 59.70W 3.50 75.77 1---- 227909.35 2189710.27 950.00 I 21.00 f----;308.00 _ __936.66 66.94N ___J~M8W 3.50 108.73 227883.84 2189731.15 .--1QP.Q,QQ.J 24.50 308.00 1028.86 90.75N 116.15W 3.50 147.40 227853.91 2189755.63 1150.00 28.00 308.00 1118.54 117.97N 151.00W__ __3.50_ __ 191.62 227819.68 2189783.63 ~125_QQQ.. 31.50 308.00 1205.34 148.52N 190.09W 3.50 - 241.23 227781.28 2189815.04 1350.00 35.00 308.00 1288.96 182.27N 233.29W 3.50 296.05 227738.85 2189849.76 1450.00 38.50 308.00 1369.07 219.10N 280.43W 3.50 355.88 227692.55 2189887.63 ~_50.00 42.00 308.00 1445.38 258.87N 331.34W 3.50 420.48 227642.55 2189928.54 1650.00 45.50 308.00 1517.61 301.44N 385.82W 3.50 489.62 227589.04 2189972.32 1721.43 48.00 308.00 1566.55 333.47N 426.82W 3.50 541.64__ -- 227548.77 2190005.26__ 1800.00 48.00 308.00 1619.12 369.42N 472.83W 0.00 600.03 227503.58 I 2190042.23._ 1900.00 48.00 308.00 1686.Q3 415.17N 531.39W 0.00 674.35 227446.06 2190089.29 ..-1000.00 -.Æi.QQ. __308.0Q__ __1752.94 460.92N 589.95W __ _ 0.00 748.66 227388.54 2190136.34 2100.00 48.00 308.00 1819.86 506.67N 648.51W 0.00 822.97 227331.03 -- --- 2190183.40 2200.00 48.00 308.00 1886.77 552.43N 707.07W 0.00 897.29 227273.51 2190230.45_ 2300.00 48.00 308.00 1953.68 598.18N 765.63W 0.00 971.60 227215.99 2190277.50 -- 2400.00 48.00 308.00 2020.60 643.93N 824.20W 0.00 1045.92 227158.47 2190324.56 2500.00 48.00 308.00 2087.51 689.68N 882.76W 0.00 1120.23 227100.96 2190371.61 2600.00 48.00 308._ºº--- _ 2154.42 735.44N 941.32W 0.00 1194.55 227043.44-----+-- 2190418.67 2700.00 48.00 308.00 2221.34 781.19N 999.88W____ 0.00 1268.86 226985.92 2190465.72 _~ c---2_800.00j_ 48.00 308.00 2288.25 826.94N 1058.44W 0.00 1343.18 226928.40 e---------_2190512.78 ~900.00 48.00 308.00 2355.16 872.70N 1117.00W 0.00 1417.49 226870.88 2190559.83 3000.00 'I 48.00 308.00 2422.07 918.45N 1175.56W 0.00 1491.81 226813.37 2190606.89 3100.00 48.00 308.00 2488.99 964.2ill'L.. ----1?34.12W._ 0.00 1566.12 226755.85 2190653.94 3200.0~0 308.00 2555.90 1009.95N 1292.68W 0.00 1640.43 226698.33 2190701.00 __ r---3300.00 48.00 308.00 2622.81 1055.70N.... ,---J351.24W 0.00 1714.75 226640.81 2190748.05 _~ 3400.00 48.00 308.00 2689.73 1101.46N 1409.80W__ ~-Q.,QD- _J 789.06 226583.29 2190795.11 3500.00 48.00 308.00 2756.64 1147.21 N 1468.36W 0.00 1863.38 226525.78 2190842.16 _~ 3600.00 48.00 308.00 2823.55 1192.96N 1526.92W 0.00 1937.69 226468.26 2190889.22 __ 3700.00 48.00 308.00 2890.47 1238.72N 1585.48W 0.00 2012.01 226410.74 2190936.27 3800.00 48.00 308.00 2957.38 1284.47N 1644.05W 0.00 2086.32 226353.22 2190983.33 3863.68 48.00 308.00 2999.99 1313.60N 1681.34W 0.00 2133.65 226316.60 2191013.29 __ ~_963.68 46.00 308.00 3068.18 1358.63N 1738.96W 2.00 2206.78 226259.99 2191059.60 4063.68 44.00 308.00 3138.89 1402.16N 1794.68W 2.00 2277.48 226205.27 2191104.37 4163.68 42.00 308.00 3212.02 1444.15N 1848.42W 2.00 2345.68 226152.49 2191147.55 4191.78 41.44 308.00 3233.00 1455.66N 1863.16W 2.00 2364.38 226138.01._ 2191159.39 f- 4291.78 39.44 ~.OO 3309.11 1495.59N [ 1914.27W 2.00 2429.24 226087.81 2191200.46 __ 4391.78 37.44 308.00 3387.43 1533.86N 1963.26W 2.00 2491.41 226039.70 2191239.8L.--.... I 4491.78 35.44 308.00 3467.88 1570.43N 2010.06W 2.00 2550.80 225993.73 2191277.43 ~91.78 33.44 308.00 3550.35 1605.24N 2054.62W 2.00 2607.35 225949.96 2191313.23 ~91.78 31.44 308.00 3634.74 1638.27N 2096.88W 2.00 2660.98 225908.45 2191347.19 4763.68 30.00 308.00 3696.55 1660.88N 2125.82W 2.00 2697.71 225880.02 --- 2191370.45 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 732.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 308.00 degrees Bottom hole distance is 4604.96 Feet on azimuth 308.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · e QRClGALII UNOCAL ,HV#10 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Wellbore: HV#10 Ver 1 Well path: HV#10 Ver 1 Date Printed: 22-Sep-2004 INTEQ 4800.00 30.00 308.00 3728.00 1672.06N 2140.13W 0.00 2715.87 225865.97 2191381.95 -- 4900.00 30.00 308.00 3814.60 1702.84N 2179.53W 0.00 2765.87 225827.27 2191413.61 5000.00 30.00 308.00 3901.20 1733.62N 2218.93W 0.00 2815.87 225788.57 2191445.27 5100.00 30.00 308.00 3987.81 1764.41N 2258.34W 0.00 2865.87 225749.87 2191476.93 5200.00 30.00 308.00 4074.41 1795.19N 2297.74W 0.00 2915.87 225711.17 2191508.58 5300.00 30.00 308.00 4161.01 1825.971\1_ 2337.14W 0.00 2965.87 225672.47 2191540.24 ---M.QO.OO 30.00 308.00 4247.61 1856.76N 2376.54W 0.00 3015.87 225633.77 2191571.90 5500.00 30.00 308.00 4334.22 1887.54N 2415.94W 0.00 3065.87 225595.08 2191603.56 -- 5600.00 30.00 308.00 4420.82 1918.32N 2455.34W 0.00 3115.87 225556.38 2191635.22 5700.00 30.00 308.00 4507.42 1949.10N 2494.74W 0.00 3165.87 225517.68 2191666.88 5800.00 30.00 308.00 4594.02 1979.89N 2534.14W 0.00 3215.87 225478.98 2191698.54 5900.00 30.00 308.00 4680.63 2010.67N 2573.54W 0.00 3265.87 225440.28 2191730.20 6000.00 30.00 308.00 4767.23 2041.45N 2612.94W 0.00 3315.87 225401.58 2191761.86 6100.00 30.00 308.00 4853.83 2072.24N 2652.34W 0.00 3365.87 225362.88 2191793.52 6200.00 30.00 308.00 4940.44 2103.02N 2691.74W 0.00 3415.87 225324.18 2191825.18 6300.00 30.00 308.00 5027.04 2133.80N 2731.14W 0.00 3465.87 225285.48 2191856.84 f-- 6400.00 30.00 308.00 5113.64 2164.59N 2770.54W 0.00 3515.ªL -- 225246.79 2191888.50 -- 6500.00 30.00 308.00 5200.24 2195.37N 2809.94W 0.00 3565.87 225208.09 2191920.16 6600.00 30.00 308.00 5286.85 2226.15N 2849.34W 0.00 3615.87 225169.39 2191951.82 ----.ß]OO.OO ~OO 308.00 5373.45 2256.94N 2888.74W 0.00 3665.87 225130.69 2191983.47 r--ºª.QQ,Qº--. ~-ºº-- _ 308.00 5460.05 2287.72N 2928.15W 0.00 3715.87 225091.99 2192015.13 ~_OO.OO 30.00 308.00 5546.65 2318.50N 2967.55W 0.00 3765.87 225053.29 2192046.79 7000.00 30.00 308.00 5633.26 2349.28N 3006.95W 0.00 3815.87 225014.59 2192078.45 7100.00 30.00 308.00 5719.86 2380.07N 3046.35W 0.00 3865.87 224975.89 2192110.11 7200.00 30.00 308.00 5806.46 2410.85N 3085.75W 0.00 3915.87 224937.19 2192141.77 7300.00 30.00 308.00 5893.06 2441.64N 3125.15W 0.00 3965.87 224898.50 2192173.43 7400.00 30.00 308.00 5979.67 2472.42N 3164.55W 0.00 4015.87 224859.80 2192205.09 7500.00 30.00 308.00 6066.27 2503.20N 3203.95W 0.00 4065.87 224821.10 2192236.75 7600.00 30.00 308.00 6152.87 2533.98N 3243.35W 0.00 4115.87 224782.40 2192268.41 7700.00 30.00 308.00 6239.4 7 2564.77N 3282.75W 0.00 4165.87 224743.70 2192300.07 7800.00 30.00 308.00 6326.07 2595.55N 3322.15W 0.00 4215.87 224705.00 2192331.73 7900.00 30.00 308.00 6412.68 2626.33N 3361.55W 0.00 4265.87 224666.30 2192363.39 8000.00 30.00 308.00 6499.28 2657.12N 3400.95W 0.00 4315.87 224627.60 2192395.05 ~ßO 30.00 308.00 6585.88 2687.90N 3440.35W 0.00 4365.87 224588.90 2192426.71 8200.00 30.00 308.00 6672.48 2718.68N 3479.75W 0.00 4415.87 224550.21 2192458.37 8300.00 30.00 308.00 6759.09 2749.47N 3519.15W 0.00 4465.87 224511.51 2192490.02 8400.00 30.00 308.00 6845.69 2780.25N 3558.55W 0.00 4515.87 224472.81 2192521.68 8500.00 30.00 308.00 6932.29 2811.03N 3597.96W 0.00 4565.87 224434.11 2192553.34 8578.18 30.00 308.00 7000.00 2835.10N 3628.76W 0.00 4604.96 224403.85 2192578.10__ All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 732.5f1 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 308.00 degrees Bottom hole distance is 4604.96 Feet on azimuth 308.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . øNGG.I.. UNOCAL ,HV#10 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 4 Wellbore: HV#10 Ver 1 Wellpath: HV#10 Ver 1 Date Printed: 22-Sep-2004 INTEQ O.OON 333.47N 1313.60N 1455.66N 1660.88N 2835.10N O.OOE 426.82W 1681.34W 1863.16W 2125.82W 3628.76W KOP End of Build End of Hold Beluqa 40 End of Drop TD 1455.66N 1863.16W 3233.00 N59 5921.97 W151 226138.01 2191159.39 15-Jan-2004 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Ri9 ( Datum #1 732.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 308.00 degrees Bottom hole distance is 4604.96 Feet on azimuth 308.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated UMOCAL \~_~-.~~=~" _-..-- - -UNOCAL- --- ---- ..-- -"·'·'-"'1 \ . _ _ LocatiOii, '·Keiia,Péiilii¿UIa. ·......sk'.- .-.., - - - ..- . ,,,.., -Hv.lo··-······ -\ field' sou", l<ønal G.' fIeld Well' HV#10 ' \ 1.ln.tall..on, HappY V.11ey Wellb....'- _""",0 V". '\ II l... ....__u,..-."..c..- -~...-.. -" - -----. ...... ---...... Scale 1 em = 100 ft east (teet) -> -4400 -4200 -4000 .,800 .3600 .3400 .,,00 .,000 .2800 .2600 .2400 .~ .- ·1800 .,600 .'400 ·1200 .,000 .ßOO -600 ....0 ~oo 0 t _c..'- ~ _ _, _ _L-'--'-- ,-1.ß--'- -' _ _,-.~..-,. _L-1. _.l...L.L .c. L L.C .-'-.. L_ ,- LJ· ..L .L-~ - -,._L.L.L.~' ..c.. 1 ~~1' ~.. ~ ~ . ^ ~ , '. " .l" \ ,800 -I " ~ \ -":, ef .¡ # \".~ J' j' 0 \ '. #. ~ ",.,,": ~ ~c, '", .;¡. \:) '. ~ \ ~~ ,~ '. ~ "" Ç:)c, ~ n;,'Ö .".... ~ \ '''I *~ ~'~ ~ ~ r#-" of ~.... <b",~- ~\:> ~" ',. ^'~& n;,"V '," '\<::! r:;:,\:> " ,,gs ~ "" . , . v n\:>" .... " <Õ' r:;:, '" ~ r:;:, ~ ' r,s <o~ ~~t§> fòt§>", ":5 ~ ~ tV ". 05 ~ "" ., ¡;:¡;:¡¡¡;¡j ,,~ r:;:, # ". ,e~ "t§><3 S) "V '~ fò\:><:::J' ~" rP S) t§> ,'!( <ôS ~' , Q) O)~ ,;::¡c, r\f ,~r§:! IS' ~ ~ r:;:, "~, ~ ~, ~ 'ò.§ò ro<§' r:;:, r:;:,\:> ~r§:! ,;::¡c:3 <, " ",.§ò r:;:, <V' "~ ~<' r§:!r:;:, , ro<3 ,,". <ë .("'¡ & ....... "3 ~<:::J', ,"" <0'<5" r:;:, ~ '....... "3 ¡§>". '.. ~ '" ¿¡ r:;:,' , #' ~ '... \:><::! ".,' "3 r:;:,\:> "IV ","3 sS> <c" ~ . ~ .'. ~ ~,\~ . . ...:::",!,-"V '. JI« S) ,........ "r§:! #'....... \ \ " ~ ", -~\/ ~ l"> ~ '~')) .. --- ~ 2800 2600 2400 2200 2000 1800 ^ . Z' 1600 Q) $ ¡ 1400 ... o Z 1200 1000 <§'<:::J s) r:;:, r,s ~<:s 'ò<:S #' r:;:,<:::J ~\:> ~ t< c.v ~ <b<§' r:;:,\:> r:;:, .. "3 n;,<3 r§:! r:;:,\:> r:;:,\:> "3 ","V n;,<::! s)\:> ~ r:;:,c, ~ ç;:,\:> ~ ~c, r\f r:;:,<:::J <V' 800 1 -t~. " -"'-.'. ",<:::J ,,'6 -._--." -. ---+- 600 r:;:,\:> ,,<3 ¢:: 0 0 400 ..... II Ë () 200 ..... (\) 11i () (/) 0 2800 7400 7000 6800 6600 6400 6~~~0 \ \ 5800 5600 5400 \ 5200 ~ 5000 4800 \ \ ~t 4600 4400 4200 4000 3800 +~~~ -2~00 -2200 -2000 -1800 _1600 -1400 -1200 -1000 East (feet) -> MOO -4200 -4()OO .3800 -3600 ·3400 -3200 -3000 ·2600 .2800 Scale 1 em:;: 100 ft -600 -400 -200 -ßOO 2600 2400 . 2200 2000 1800 ^ , 1600 Z o ~ 1400 ~ ø' ('0 1200 .è . 1000 800 600 Cf) o 400 ~ o 3 200 II ..... o o -0 ;:;> o . SA HUGHES INTEQ Scale 1 cm = 20 ft -800 -760 -720 480 440 400 360 320 280 ^ 240 I - - CD 200 J!! - :5 ... 160 0 Z 120 80 40 0 ¡: 0 N II -40 E () ...... Q) -80 -æ 0 (/) ] }'iO<¡ ~ L, !;)~ "G V'c? Vo e -680 ~ UNOCAL I I -j I UN V'¿ Va 76] Vo Location: Kenai Peninsula, Alaska Field: South Kenai Gas Field Installation: Happy Valley Slot: HV#10 Well: HV#10 Wellbore: HV#10 Ver 1 -640 East (feet) -> -440 -400 -360 -320 -280 r ,-, --,- -'- ~ ~ f"·i j I ~ -600 -560 -520 -480 I~L~I I --L-L-L_L_-L____L ~. -240 -200 -160 -120 -80 -40 o 40 L-L~_~_~I c;~ ~ 3700 , ~...-l~1 L~ I L ~ ~ '^'~~ "~ ~ 1600 ~~ ~ 1500 .~C;... " ~ 1400 ~~~ ~ ~o ~ 11 c.... 1100.A~~ 7.900 /..~ . "'7. Vo A~ú'a, ~Oc0~:go "'9'Q v V 900 ~OO 700 600 .>. 0 200 6'00 00 .+ . 7 .$- ... 6'00 ÓÒo "'00 f/' "'00 ./~7'5iQ . 76] óò. v r£~/;&o:--'oo Vo v 2800' <o~ " ~~ "b1 -,- ~ "'& Vo "'&Q V "'->c>. v "'6] Vo ú'7. 00 ú'Q Vo 7ó) Vo 7% ~b 703 °0 ~ Vo ,----, I I -,--, -800 -760 -720 -680 -640 -600 Scale 1 cm = 20 ft 2700 3500 3400 \ 3300 2300 320~\>2600 3100 \ "'...2500 3000 \ 2900 " 2100 ; 2200 o 2100 .... 2400 2800 .. ~ 2000 ¡;)~ ,,'" 2700 \ 2600 \ 2300'", . 1 1900 t " 2200 .# ~;';;:!~~~ t 1500 ~~ ....." ~~ \ 2500 ~" \ !:) .....2400\\~~1:S .-..-- ... 2300 '. + 2200 '.... 2100" . 1900····....... .' 13.0.0......~ 1300', ~ ./ \~~ 200 it!f. 200~ 110~ 1-1\1#'\ 7 76] 7óJ ->c>. Vo Vo v "'ó) Vo 7Q Vo .900 77 00 -560 -520 -480 -440 -400 -360 -320 -280 -240 -200 East (feet) -> 40 -160 -120 -80 -40 o 480 440 400 __ 360 320 280 240 ^ I Z 200 0 ;+ ::T - .... 160 m - - 120 . 80 40 -0 CIJ C") Q) CD -40 C") 3 II -80 N 0 ;:> . . UNOCALe UNOCAL HV#10 Ver 1, HV#10 Ver 1 HV#10, Happy Valley CLEARANCE LISTING Page 1 Date Printed: 10-Sep-2004 South Kenai Gas Field, Kenai Peninsula, Alaska INTEQ Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and Maqnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of fl/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Hole size/Casinqs are NOT included Hole size/Casinqs ARE subtracted from Centre-Centre distance Ellipses scaled to 2.85standard deviations. Closinq Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation HV#9 Happy Valle 6 Happy HV#5 HV#5 113.94 893.66 893.66 109.23 902.23 19.24 1000.66 Valle 5 I HV#8 HV#8 HV#8 114.05 1436.38 104.33 1426.48 6.88 1853.67 Happy HV#4 HV#4 118.58 968.39 114.69 984.25 20.55 1131.89 Vª"ID'tM Happy HV#3 HV#3 Happy Valley 125.13 918.64 120.06 935.04 19.17 1033.46 Valle~ Happy HV#1 HV#1 Happy Valley 151.68 0.00 650.0Þ 152.25 32.81 43.62 1099.08 Valle-'Li£1. 173.39 +-- 0.00 ~~py HV#2 HV#2 Happy Valley O.OO! 173.89 0.00 42.23 1017.06 I Valle 2 HV#7 HV#7 Ha 216.45 I 756.63 756-:e- 213.19 787.40 32.44 1197.51 HV#7 I All data is in Feet unless otherwise strted Coordinates are from Slot and TVD's are from Rig ( Datum #11732.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (1 D) Prepared by Baker Hughes Incorporated . . UNOCAL. UNOCAL HV#10 Ver 1, HV#10 Ver 1 HV#10, Happy Valley CLEARANCE LISTING Page 2 Date Printed: 10-Sep-2004 South Kenai Gas Field, Kenai Peninsula, Alaska INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Datum #1 732.5ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (1 D) Prepared by Baker Hughes Incorporated """,\., ....'~OFAI.. I, :.... ~~··......···1J'. " - r~.·· . "~ " --.I' .-y ..... * ....49.lli .... * ~ "..................................., -' tf1' tf1' "" f!" . . . . .. .. .. .. .. .. . . .. . . . .. . .. .. . " , , ~ ". M. SCOTT McLANE;" ..... I' ~ '. : ~ - , ~ ". 4928-S ....D'- ''f.! .... .... if'- " ~ ~ .......... ~~ - , " 7i'oF-tss JON"'\. \.. ,........ ,\\""" OILWELL RD. SCALE 1 inch = 300 ft. o JOO 450 r-..-.- 1 J 600 I NOTES 1) BASIS OF COORDINATES: NGS CORS STATION "KEN 1" NAD27 ALASKA STATE PLANE ZONE 4. 2) BASIS OF ELEVATION: NGS BM W75 NAVD88. 3) SECTION LINE OFFSETS DERIVED FROM TIES TO BLM MONUMENTS AT SW CORNER SECTION 10 AND SE CORNER SECTION 12 T2S R13W SM FOUND THIS SURVEY 1296' FEL PROPOSED WELL HV#10 GRID N:2189662.286 GRID E:227967.990 LATITUDE: 59°59'07.642"N LONGITUDE: 151°29'07.668"W ELEV. 716' HAPPY VALLEY NO.1 PAD --1 (J) lL... CO ..- ..- SECTION 22 TOWNSHIP 2 SOUTH RANGE 13 WEST SEWARD MERIDIAN ALASKA HAPPY VALLEY NO. 10 WELL AS-STAKED SURFACE LOCATION NINILCHIK, AK P.O. 80x 468 SOLOOTNA. AK 99669 Project: 043070 Consulting C; roup Testing Dwg:043070 TEL 907.28:3.4218 FAX 907.283.:3265 Revisions: Date: 9/2/04 Grid SEC 22 SEC 23 SEC 27 SEC 26 APPLICANT: UNDCAL . 909 W. 9th Avenue W Anchora e, AK 99519-7685 FIGURE: 1 One Hundred Dollars And 00 Cents************************************************************* 23-SEP-04 >'<******>'0'< 100.00 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501 United States III 2 0 0 7 8 ¡ 8 III I: 0 J ¡ ¡ 0 0 2 0 g I: J g ¡ ¡ 8 ¡ J 7111 . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~"" ~/l.1 PTD# :20 9- /e-~ 11/0 )< Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUE"· APPLIES (OPTIONS) MlJLTI Tbe permit is for a new wellbore segment of LATERAL existing wen . Permit No, API No. . (If API number Production. sbould continue to be reported as last two. (2) digits a function 'of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), aJI (PH) records, data and logs acquired for tbe pilot hole must be dearly differentiated In both name (name on permit plus PH) .' and API Dumber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.055~ Approval to X perforate and produce is contingent upon issuance of ~ conservation order approving a S~ ..I/~ spa cing ex ception. (Company Name) assumes tbe liability of any I"~ ~~ .J;., protest to the spacing .exception tbat may ~ 1.!7 '>~:r ~ 0 r J4,5 occur. A!?-.r_ .. /'-..ð" , / " DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE CommissioD must be in no greater ·tban 3D' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample iJiter:vals through target zones. .' . . The permit is approved subject to full compliance with 20 AAC 25.055 and to UNOCAL's submission to the Commission of an application for pool rules for the Deep Creek Unit before November 15,2004. Field & Pool HAPPY VALLEY, UNDEFINED GAS - 290500 Well Name: HAPPY VALLEY 10 Program DEV Well bore seg D PTD#: 2041860 Company UNION OIL CO OF CALIFORNIA Initial ClassfType DEV 11-GAS GeoArea Unit On/Off Shore On Annular Disposal D Administration 1 p~(I"lJitfee attacheJJ_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leas~number _appropriate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nique wellnam~_and lJijmb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ . _ _ _ 4 WelUocated in_aciefineJJ_ppol _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WellJocated proper _distance_ from driJling unitb_ound_a'Y_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ The_Happy: Valley: accumulatiolJ hasbeeo ditfjculUo develop for thre_ereasons; 1)strucutural complexity, _ 6 WellJocated proper distance_ from otber wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ 2)djscontilJouHeservoirsand 3) low perrneabjlity_s_ands, The small çt(illjn.9_units_ Unocal has_ ijsed bere _ 7 _S_utfjcientacreage_aYailable in_drilJilJg unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ are a result ofJhe_se threeJaGtor$.UnocaJ appliedJoraspacing_exœption_ concurreotly witb this_permit _ _ 8 Kdeviated, is weJlbore platiocJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Ye$ _ _ Permit aPPJoval must be contin.geotonll ObtainilJg a spacing exceptioo aod 2)apply:ingJor_p_oolrules_ _ _ _ _ _ _ 9 _Operator only: affected party_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ for the Deep_creek Unit before Npvember t5, RPC _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Operator bas.appropriate_bond inJorce _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ Xes _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ 11 Pe(lT]it c¡;¡n be issued witbout co_nserva.tion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Pe(l1) it call be issijed witbout admioistrative_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 9/23/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocat~d within area and_strata authorized by_llJjectioo Order # (puUOiI in_c_ommellts).(For NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AJI wells_withtnJl4_mile_are.a_of reyiew id~lJtified (For servic_ewe!l only). _ _ _ . _ _ _ _ _ _ _ _ _ . _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre.-produ_ced illjector; JJuration_of pre-proJJuctipo le$S than:3 months (For_servtce well onJy) _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _ACMPFindjng.of Consistencyha$ been Jssued_ fortbi$ project _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 18 19 20 21 22 23 24 25 26 27 Appr Date 28 WGA 9/24/2004 129 '30 31 32 33 34 Geology 35 Appr Date 136 37 RPC 9/23/2004 38 39 Geologic Commissioner: bJs . _C.ollductor string_PJovided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xe$ _ _ _ _ _ _ _ 13_-:3/S"@£8'._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _S_urface_casJngpJotects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _CMTvoladeQijatetocirculateoncond_uctor_&$uJfcs9 _ _ _ _ Y~$ _8deJ:uateexcess, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _CMT vol adeQuateto tie-inJongstrillg to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ CMTwill coyer_all koownpro_ductiye bori~on_s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Casing de_signs ad_eClua_te for C,.T, B_&_permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Adequatetankage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ Nabors 129. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Jfa.re-d(iII~ has a to-403 fOJ abandonment be~1l aPPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ \Jew welt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _AJJequatewe!lbore. separatio_n_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Jfdiverteneq_uired, does itmeet reguJatioos _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ Waiyeuequested. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _DJillillgfJuid_prQgram$chematic&eq.uipJi$tadequat~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _MaxMW_9Appg. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _BOPEs,_dothey meetreguJatioo _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ BOPEpress ra_tilJg app(op(iate;testto_(pu.t psig incommeots)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ Test to_35QO_psLMSF> 19_80 psi. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ChOke_manifold compJies w/API RF>-53 (May 84) _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Work will pcc_ur withputoperatjon _shutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Js presence_ of H2S gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ MechanicalcplJdJtionof we.lls within 80R yerified (Forserv]ce welJ onJy) _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - - - - - - - - - - - - - Pe(lT]it call be iS$ued wlo_ hydrogen sulfide meaS_u(es _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _D_ata_PJeseoted on potential oveJpressurezones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _S~ismicanalysJs of sbaJlow gas_zolles _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Seabed _conditioo survey (if off-sh_o(e) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Contact namelphoneJor_weekly progress.reports [exploratp'Y_only] _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Date: 1121- ( ~ Engineering Commissioner: Ff Date Date e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. PPY LLEY#10 Section 22 T2S R13W SM Deep Creek Unit Kenai Borough, Alaska L EPORT September 27, 2004 to October 12, 2004 Lees Browne, Jr. - Logging Geologist John Morris - Sr. Logging Geologist Brian O'Fallon - Sr. Logging Geologist . . . UNOCALe Happy Valley #10 TABLE OF CONTENTS WE LL RE SUM E ........................................................................................................................................... 3 PROCEDURES and GENERAL DiSCUSSiON........................................................................................... 5 GEOLOGICAL DISCUSSION ......... .... .......................... .......... ................................ ..................................... 6 DAILY ACTIVITY SUMMARY ...................................................................................................................... 7 LITHOLOGY REViEW............. ..................................................................................................................... 9 SU RVEYS...................................................................................................................................... ............. 23 DAILY MUD PROPERTIES ...................................... ................................................................................. 27 BIT RECORD . .... .............. .................. ........................ ............................................ .................................... 28 MO RN I NG RE PO RTS ................................................................................................................................ 28 FINAL WELL LOGS ................... .................................................................................................. Appendix I [:I El~()CH 2 UNOCAUÞ Happy Valley #10 · WELL RESUME Company: Unocal Alaska Resources, Inc. Well: Happy Valley #10 Field: Deep Creek Region: Cook Inlet Location: Section 22, T2S, R13W, SM Coordinates: 1118' FSL,1296' FEL Elevation: Rig floor elevation = 732.4' AMSL GL = 716.0' AMSL County, State: Kenai Peninsula Borough, Alaska API Index: 50-2312 -00-28 · Spud Date: September 27 , 2004 Total Depth: 8420' Contractor: Nabors Drilling Alaska Company Representative: Donnie Fowler, Doug Niehaus, Jim Brown Rigrrype: Nabors #129/ Land Epoch Logging Unit: #30 Epoch Personal: Lees F. Browne Jr. John Morris Brian Q'Fallon Company Geologist: Mark Lynch · ~ El10CH 3 · · · UNOCALe Happy Valley #10 Casing Data: 13 3/8" landed at 56' 9 5/8" landed at 943' 7" landed at 3849' Hole size: 12 }'4'''' to 955' 8 }12"" to 3860' 6 1/8" to 8420' Mud Type: Spud to 955' EZMUD to 8420' Logged Interval: Full Logging below conductor @ 56' Electric Logging Co: Schlumberger Logs Run: Single Quad Combo ~ El~()CH 4 UNOCALe Happy Valley #10 · PROCEDURES and GENERAL DISCUSSION Epoch supplied a fully computerized DML (Digital Mudlogging) Unit and a RIGWATCH Digital Drilling Instrumentation System (which included measurements block height, drill rate, pit volumes, pump rates, pump pressure, flow line, return flow, hook load, torque, and rotary speed) for all operations. Display monitors for the company man, tool pusher and mud engineer, and touch-screen (Azonix) displays for the driller and pit watcher provided graphics of the information. Hydrogen flame ionization (FID) Total Gas and (FID) Gas Chromatograph instruments detected and analyzed formation gases. Mud gas was continuously generated by an optimally positioned Quantitative Gas Measurement (QGMTM, Texaco patent) electrically driven gas trap, and drawn to the detectors by vacuum pump. The gas system was tested and calibrated on a regular basis. Unocal Alaska Resources, Inc. spudded Happy Valley #10 on September 27th, 2004 with Nabors Drilling Alaska #129. Epoch commenced DML TM logging on the same day at the top of the hole fill of the 13 3/8" conductor pipe at 56'. Epoch commenced logging in 12 XU" surface hole which was drilled with water base spud mud from surface to 955' and completed on September 27th, 2004 with no drilling problems. A carbide was dropped at 955' showing a nearly gauged hole. Surface casing, 95/8", was run and set at 943' with no problems. The 8 %" intermediate hole was drilled from 955' to 2792' and the drill pipe became stuck during a connection. Worked the stuck pipe with no luck and pumped oil base mud as a spotting fluid and worked the pipe with no luck. Ran a free point and tripped out with the string. Ran in the hole with a fishing tool and pulled fish free right away. Drilled 30' with the fish and tripped out for a new BHA. No other significant drilling problems were experienced down to 7" casing point at 3860'. Carbide lag showed gauged hole. · Intermediate casing was set at 3849', and the well was drilled to a total depth of 8420' with no significant problems with normal drilling. However, three intervals were cored, Core #1: 4503' to 4510', Core #2: 4546' to 4636', and Core #3: 7826' to 7859'. For each core an interval of 90' was attempted, and only Core #2 was drilled successfully with full recovery. Core #1 managed only 7' with 3' recovery, and Core #331' with only 3' recovery. Total Depth was reached 1:22 am on October 12, 2004. A carbide lag showed approximately 29 barrels over gauged hole. Cuttings collection and analysis commenced from under conductor pipe on September 2it\ 2004. Cuttings samples were caught at thirty foot intervals and at smaller intervals if the drill rate allowed during high gas intervals to 8420'. Ten foot spot samples where caught depending on the rate of penetration. Down hole electric wireline data was obtained by Schlumberger. · [:I El~OC·H 5 UNOCALe Happy Valley #10 . GEOLOGICAL DISCUSSION Happv Vallev #10 The primary objectives of Happy Valley #10 were quality Beluga and Tyonek formation gas sands. Numerous zones of interest were encountered. The following intervals include sand or graded sands or sandy zones with significant gas increases over background, some of which are coal enhanced. The high gas is listed for each interval. Geologic Descriptions encompassing these intervals can be found in the Lithology Review in this report: INTERVAL GAS (UNITS) REMARKS 4540' to 4555' 79 Massive Sand 5405' to 5542' 571 Massive Sand 5458' to 5535' 1313 Massive Sand 5823' to 5838' 458 Sandy Zone 6323' to 6370' 635 Sandy Zone (coal enhanced) 6625' to 6638' 695 Sandy Zone (coal enhanced) 7230' to 7250' 762 Massive Sand 7330' to 7390' 960 Massive Sand (coal enhanced) 7480' to 7500' 1762 Upward Fining Sand (coal enhanced) 7540' to 7590' 972 Massive Sand 7649' to 7663' 873 Sandy Zone 7695' to 7712' 815 Upward Fining Sand (coal enhanced) 7828' to 7859' 169 Upward Fining Sand (cored interval) . 7859' to 7992' 700 Massive Sand (drilled interval) 7927' to 7937' 554 Sandy Zone (coal enhanced) 8185' to 8250' 1562 Massive Sand 8300' to 8320' 794 Sandy Zone (coal enhanced) . ~ El)()CH 6 UNOCALe Happy Valley #10 · CAlLY ACTIVITY SUMMARY (Note: All daily summaries reported at 24:00:00 of listed date.) 9/27/04 Finish rigging up and spudded the well on 9/27/04. Drilled formation to 955' (casing point), and circulated bottoms up and a carbide to show a nearly gauged hole. Pulled out of the hole and lay down the smart iron and rig up to run 9 5/8" casing. 9/28/04 Run and land casing and pumped a cement job to the casing. Held 3500 psi for 30 minutes and nipple up and test BOPE. 9/29/04 Finished testing BOPE and pick up BHA and drill pipe. Trip into the hole and drill out 10' of new formation and performed a Leak Off Test to 14.8 EMW and drilled ahead with slight mud loss from 1000' to 1200'. 9/30/04 Drilled formation to 2793' and pulled up to make a connection, in which the drill string became stuck in the hole. Could not go up or down or rotate. No increase in pump pressure. Worked the drill pipe and spotted 1000' of oil base mud and continued to work the pipe. · 10/1/04 Continue to work the stuck pipe with pumping one barrel of oil base mud every 2 % hours. Rigged up wire liners and ran a free point. Picked up the string shot and shot the pipe with no luck. Rigged up and shot a second string at 2685'. Pipe came loose and circulated out the opil base mud and dumped it. Pulled out of the hole and lay down cross over and two flex collars. Picked up fishing assembly and mixed fishing tool spotting fluid. Tripped into the hole to the shoe and cut and slipped new drill line. 10/2/04 Trip in the hole with cut lip fishing assembly. Tagged the fish at 2686' and screwed into it. Worked fish down hitting the bumper sub, fish came free, tagged bottom at 2792' and drilled to 2823', no mwd pluse, circulated bottoms up (8 units of trip gas), and pulled out of the hole. Wash and ream to the shoe, lay down fishing assembly and repair the top drive, pick up bha and trip in the hole to drill. 1 0/3/04 Finish tripping in hole and drill from 2823' to casing point at 3860'. Circulate bottoms up, circulate LCM sweep, and drop and circulate out carbide. Short trip to 2600', rotating and circulating through tight spots. Trip in hole and condition mud, 35 units of trip gas. Pull out of hole and monitor well at shoe. Pulling BHA at midnight. 10/4/04 Finished pulling out of hole with BHA and laid down string. Rigged up and ran 7" casing. Rigged up and cemented casing. Pressure tested to 3500 psi, and nippled up and tested BOPs. Picked up new BHA with 61/8" bit, and picked up and ran in hole with DP, while cleaning pits and mixing new mud. · 10/5/04 Tripped in hole to 3752' and tested casing to 3500 psi for 30 minutes. Performed choke drill and drilled out cement and shoe and 20' of new formation down to 3880'. Displaced hole with new mud and performed LOT to 13.7 ppg emw. Drilled ahead, rotating and sliding, to core point at 4503'. Circulated hole clean and pulled out of hole for core barrel. 1 0/6/04 [;1 EIJOCH 7 UNOCALe Happy Valley #10 · Trip in hole and core from 4503' to 4510', core barrel jammed, and pull out of hole. Recovered 3' of core and picked up drilling assembly. Run in hole and drilled at 5' intervals from 4510' to 4545', circulating out after each interval looking for sand. Pulled out of hole to pick up core barrel, and begin running in hole with core barrel. 10/7/04 Run in hole with core barrel assembly and core from 4546' to 4636'. Circulate bottoms up and pull out of hole with core barrel. Pick up drilling assembly and run in hole. Drill from 4636' to 4984' 10/8/04 Drilled from 4984' to 5931', and circulated bottoms up to search for core point. Drilled ahead to 6030' and circulated bottoms up, and drilled and circulated bottoms up 7 more intervals down to 6105' searching for core point. Determined not to core, and performed wiper trip, reaming through tight spots on trip out. Drilled ahead from 6105' to 6109' 10/9/04 Drilled ahead from 6109' to 7131'; circulated bottoms up; wiper tripped to 6057'. Pulled through some tight spots of 20K over. Washed down final stand through tight spot 30' off bottom, and drilled ahead, from 7131' to 7618'. 10/10/04 Drilled ahead from 7618' to 7828', circulated bottoms up and decision was made to core. Pulled out of hole and picked up coring assembly. Ran to bottom, pumping through tight spot a 7177', and cored, trip gas 715 units, from 7828' to 7859'. 10/11/04 Finished coring just after midnight and pulled out of hole and laid down core. Pick up drilling assembly · and ran in hole to shoe, cut drilling line. Ran in hole to bottom, and drilled from 7859' to 8347'. 10/12/04 Drill from 8346' to 8420', total depth, and circulate out. Wiper trip 7 stands and circulate on bottom, 605u of wiper gas, drop carbide pill, 4720 strokes or 29 barrels over gauge, and continue circulating and conditioning hole. Trip out of hole for e-Iog, and lay down BHI tool for download. Rig up and run Schlumberger wireline down to 7863'. Unable to get past 7863', and logged out of hole. Make second run and have trouble getting down through casing, and found damaged strand in wireline cable with tool at 2700'. Pulled out of hole and laid down damaged cable. Rigged up and tested BOPs. · [:I EI'OCH 8 UNOCALe Happy Valley #10 · LITHOLOGY REVIEW Commence logging Happy Valley #10 at 10:00 on 9/27/2004. Tuffaceous siltstone (60' to 90') = pale yellowish brown; poor to moderate induration; crumbly to crunchy; sectile to malleable; flexible in part; mushy to pasty in part; slimy; becoming stiff; moderate cohesive to slight adhesive; earthy fracture; sub nodular habit; dull earthy luster; clayey to silty texture; massive gradational beds of silt and clay; composed of 70% silt, 30% clay; interbedded tuffaceous blebs; very detritalish; scattered minor coal beds of lignite to bituminous. Sand (155' to 210') = light gray overall with mostly milky white, light to medium gray, occasionally light to medium greenish gray, rare reddish orange; clasts range from very fine lower to medium upper; dominantly very fine to fine range; angular to subround, dominantly subangular to subround; moderately sorted; composed of dominantly quartz with minor metamorphic lithics; traces of jasper; silty; argillaceous; slight acid reaction; scattered chunks of free lignite; estimated fair to poor porosity and permeability. Tuffaceous claystone (225' to 280') = light to medium gray with slight yellowish brown hues; very soft to occasionally slightly firm; mushy to crumbly; dominantly appears as lumpy clay, occasionally as poorly indurated irregular to rarely subblocky cuttings; earthy, dull luster; smooth to moderately gritty texture; non to occasionally very slightly calcareous; local thin carbonaceous lams; occasional thin seams of lignite; occasionally very silty, grading to and interbedded with siltstone. · Sand (295' to 320') = light gray overall with slight "peppered" appearance; common milky white, light to medium gray, light to medium greenish gray, clear, occasionally reddish orange; clasts range from very fine lower to medium upper, dominantly fine range; angular to subrounded, dominantly subangular to subround; moderately sorted in the fine range; composed of 70% quartz, 30% metamorphic lithics, scattered jasper. Tuffaceous siltstone (345' to 390') = light to medium brownish gray to occasionally pale yellowish brown; soft to occasionally moderately firm; crumbly to occasionally slightly brittle; irregular and occasional roughly subblocky cuttings; matte luster with common sparkles; gritty, abrasive texture; non calcareous; scattered pinpoint carbonaceous specks; rare carbonaceous lams; argillaceous; grades to and is interbedded with tuffaceous claystone; scattered thin streaks and specks of lignitelcarbonaceous matter. Sand (420' to 480') = very light to light gray overall with occasional "peppered" appearance; common milky white, light to medium gray, light to medium greenish gray, clear; occasionally medium to dark reddish orange; clasts range from very fine lower to coarse lower; dominantly fine grain; angular to rounded, dominantly subangular to subround; poor to moderate sorting; scattered to common frosted grains; occasional broken grains due to bit action; occasional pitted grains; composed of 80% quartz, 20% meta lithics; traces of jasper; silty; lower portion with traces to 10% granules and granule fragments. Tuffaceous claystone (490' to 540') = light to medium brownish gray, pale yellowish brown; very soft to rarely moderately firm; mushy to crumbly; dominantly appears as clay with common slightly firm lumps, occasionally as subblocky poorly indurated cuttings; matte, earthy luster with occasional sparkles; smooth to moderately gritty texture; non calcareous; scattered carbonaceous specks and streaks; rare thin laminations of lignite. · Tuffaceous siltstone (540' to 590') = light to medium brownish gray to occasionally pale yellowish brown; soft to occasionally moderately firm; crumbly to occasionally slightly brittle; irregular and occasional roughly subblocky cuttings; earthy luster with common sparkles; gritty, abrasive texture; non calcareous; scattered pinpoint carbonaceous specks; rare carbonaceous lams; argillaceous; grades to and is interbedded with tuffaceous claystone. ~ El~OCH 9 UNOCALe Happy Valley #10 · Tuffaceous claystone (600' to 660') = light to medium gray with slight yellowish brown hues; very soft to occasionally slightly firm; mushy to crumbly; dominantly appears as lumpy clay, occasionally as moderately indurated irregular to rarely subblocky cuttings; earthy, dull luster; smooth to moderately gritty texture; non to occasionally very slightly calcareous; local thin carbonaceous lams; occasional thin seams of lignite; occasionally very silty, grading to and interbedded with siltstone. Coal (660' to 700') = black to dusky brown; firm to moderately hard; crumbly to moderately brittle; flaky, irregular and blocky cuttings; dull to slightly resinous luster; smooth to slightly rough surface texture; occasional thin woody lams; thinly interbedded with tuffaceous claystone. Sand (700' to 770') = very light gray overall; dominantly milky white, clear, light to medium gray, occasionally light to medium greenish gray, rarely dark reddish orange; clasts range from very fine lower to medium upper, dominantly very fine to fine; angular to rounded, dominantly subangular; composed of 90% quartz, 10% meta lithics; trace jasper; no acid reaction; totally unconsolidated in samples; clay matrix inferred; estimated fair porosity and permeability; tuffaceous siltstone (770' to 795') = light to medium brownish gray, pale yellowish brown; soft to moderately firm; crumbly to occasionally moderately tough; irregular shaped cuttings; matte luster with common sparkles; gritty, abrasive texture; non calcareous; argillaceous; grades in part to and is interbedded with tuffaceous claystone; scattered to common carbonaceous specks; thin beds of carbonaceous shale. · Sand (800' to 920') = very light gray overall; dominantly milky white, light to medium gray, light to medium greenish gray, clear, occasionally dark reddish orange; clasts range from very fine lower to medium upper, dominantly very fine to fine; angular to rounded, dominantly subangular to subround; common frosted grains, occasional pitted grains; composed of 80% quartz, 20% meta lithics, trace jasper; grain size increases with depth so that by 900' grains range from very fine to granules with fine to coarse dominating; lower zone is 60% quartz, 40% meta lithics; totally unconsolidated throughout; no acid reaction; estimated fair to good porosity and permeability. Tuffaceous claystone (920' to 950') = light brownish gray, pale yellowish brown, occasionally light to medium greenish gray; very soft to occasionally firm; mushy to occasionally moderately brittle; blocky and irregular cuttings; matte luster smooth to moderately gritty texture; non calcareous; interbedded with tuffaceous siltstone. Sand (975' to 1035') = very light gray overall; common milky white, light to medium gray, light to medium greenish gray; occasional pale yellowish brown, reddish orange, black; clasts range from very fine lower to medium upper; mostly fine range; angular to rounded; moderate sorting in the fine to medium range; composed of 70% quartz, 30% metamorphic lithics; trace amount of jasper; totally unconsolidated in the samples; some grains with a thin crust of calcite; clay matrix inferred. Tuffaceous siltstone (1035' to 1100') = light brownish gray, occasionally with slight greenish hues; soft to firm; crumbly to occasionally moderately tough; irregular, blocky and subblocky cuttings habit; matte, earthy luster with scattered micro sparkles; gritty, abrasive texture; argillaceous; locally common very fine sand grains; occasional thin carbonaceous laminations and streaks; scattered micro mica. Tuffaceous claystone (1105' to 1180') = light to medium gray, medium to dark brownish gray, occasionally light to medium greenish gray; very soft to firm; mostly appears as clay with slightly firm lumps; occasionally as moderately indurated subblocky and irregular cuttings; mushy to crumbly, occasionally moderately brittle; matte luster; smooth to moderately gritty texture; scattered to abundant very fine to medium sand grains disseminated throughout; common carbonaceous specks and streaks; locally moderately calcareous; locally very silty, grading to and interbedded with tuffaceous siltstone. · Sand (1190' to 1260') = light gray with slight greenish hues overall; mostly milky white, light to medium gray, light to medium greenish gray, occasionally moderate brown, rarely reddish orange; clasts range from very fine lower to very coarse upper; the majority of grains are fine to medium range; angular to rounded, dominantly subangular to subround; poorly sorted overall; moderately sorted in the fine to [:I El~()CH 10 I I I UNOCALe Happy Valley #10 medium grain range; composed of 70% quartz, 30% metamorphic lithics, trace amounts of jasper; totally unconsolidated in samples; slight acid reaction; clay matrix inferred; estimated poor to fair porosity and permeability. Sand (1270' to 1350') = light to medium gray overall with slight greenish hues; grains are milky white to clear, light to medium gray, light to medium greenish gray, black, rarely dark reddish orange; clasts range from very fine lower to coarse upper, dominantly fine to medium range; angular to rounded, mostly subangular to subround; moderately sorted in the fine to medium range; common frosted grains; composed of 60% quartz, 40% metamorphic lithics; rare jasper; many grains have a thin crust of calcite on surfaces; moderate to vigorous acid reaction; clay matrix inferred; estimated fair porosity and permeability. Tuffaceous siltstone (1360' to 1415') = light to medium brownish gray, pale yellowish brown; moderate brown; soft to firm, occasionally moderately hard; irregular and occasionally subblocky cuttings; earthy luster with scattered micro sparkles; grainy, silty texture; non to locally moderately calcareous; common carbonaceous specks and streaks; scattered micro fine mica; grades to and is interbedded with tuffaceous claystone. Sand (1425' to 1505') = light to medium gray overall with common greenish hues; grains are milky white to clear, light to medium gray, light to medium greenish gray, black, rarely dark reddish orange; clasts range from very fine lower to coarse upper, dominantly fine to medium range; angular to rounded, dominantly subangular to subround; moderately sorted in the fine to medium range; 70% quartz, 30% metamorphic lithic fragments; trace to scattered jaspèr; unconsolidated in sample; scattered grains have a thin calcite crust; clay matrix is inferred; estimated fair porosity and permeability. Tuffaceous claystone (1510' to 1580') = light to medium gray, medium to dark brownish gray, occasionally light to medium greenish gray; very soft to firm; mostly appears as clay with slightly firm lumps; occasionally as moderately indurated subblocky and irregular cuttings; mushy to crumbly, occasionally moderately brittle; matte luster; smooth to moderately gritty texture; scattered to abundant very fine to medium sand grains disseminated throughout; common carbonaceous specks and streaks; scattered thin coal and carbonaceous shale seams. Sand (1590' to 1650') = light greenish gray overall with "peppered" appearance; significant increase in greenish gray metamorphic lithic fraction; clasts range from very fine lower to very coarse lower; angular to rounded, dominantly subangular to subround; moderately sorted in the fine to medium size range; composed of 50% quartz, 50% metamorphic lithics, common black mafic minerals; unconsolidated in the samples; slight acid reaction; clay matrix inferred; estimated fair to good porosity and permeability. Carbonaceous shale (1655' to 1700') = black to dusky brown; firm to hard; brittle, moderately tough; tabular and blocky cuttings habit with common parallel and occasional sub conchoidal fracture; dull to resinous luster; smooth texture; occasional moderate brown colored laminations. Tuffaceous claystone (1700' to 1785') = light to medium gray, light to medium brownish gray, rarely very light to medium greenish gray; very soft to firm; dominantly appears as clay with com slightly firm lumps; occasionally as moderately indurated subblocky and irregular cuttings; mushy to crumbly, occasionally moderately brittle; matte luster; smooth to mod silty texture; non calc; common carbonaceous specks and streaks. Carbonaceous shale/coal (1790' to 1805'}black to grayish black; brittle to firm; resinous to earthy luster in carbon shale; matte to striated/woody texture; planar fracture along shale partings; composed of carbonaceous shale with thin beds of lignite; bleeding gas. Sand (1820' to 1845') = medium light gray; clast size coarse lower to fine upper; angular to sub angular; poor to moderate developed sphericity; moderate sorting; chipped to impacted texture; sub mature nature; non to slight siliceous cement; slight to moderate clay matrix; grain supported with secondary [:I El"JOCH 11 I I I UNOCALe Happy Valley #10 matrix support in parts; composed of 60% quartz 30% metalithics, 10% chert and various material; fair porosity and permeability no oil indicators. Sand (1850' to 2050') = medium gray; clast size coarse upper to very fine lower; sub round; moderate to well developed sphericity; very poor sorted; polished to impacted texture; sub mature non to very weak siliceous cement; slight to moderate clay matrix; grain and matrix support with increase in matrix support with depth; composed of 50% quartz, 40% metalithics, 10% chert and various lith fragments; fair porosity to poor at 2040no oil indicators. Sand (2060' to 2010') = medium gray; clast size range coarse lower to very fine upper; sub round; moderate to well developed sphericity; very poor sorting; polish to impacted texture; sub mature; non to very weak siliceous cement; slight to moderate clay matrix; grain support with secondary matrix support; composed of 50% quartz, 40% metalithics, 10% chert, feldspar, muscovite and various lithic fragments; fair porosity and fair to poor permeability; no oil indicators. Sand (2020' to 2070') = dark gray; clast size range coarse upper to fine upper; moderate developed sphericity; poor sorting; pitted texture; sub mature; non to very weak siliceous cement; slight to moderate clay matrix; both matrix and grain support; composed of 70% dark gray metalithics, 30% quartz; very distinct color change; fair porosity and fair to poor permeability; no oil indicators. Tuffaceous claystone (2080' to 2130') = pale yellowish brown; very soft; lumpy to clumpy; clustered to clotted; gelatin mushy to pasty; tacky to slimy; non to slight cohesiveness; slight adhesiveness various tenacity and consistencies; amorphous fracture; massive habit; dull earthy luster; colloidal texture; gradational beds of tuffaceous claystone composed of 80% clay, 20% silt; thin to thick beds of coal. Carbonaceous shale/coal (2140' to 2160') = black to grayish black; firm; earthy to resinous luster; matte texture; blocky fracture; composed of very carbonaceous shale grading to lignitic coal; slight visible bleeding gas noted. Tuffaceous claystone (2170' to 2220') = medium gray; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky to slimy; non to slight cohesive; slight to moderate adhesive; earthy fracture; massive habit; dull earthy luster; colloidal texture; massive beds of gradational clay with interbedded sands. Sand (2230' to 2260') = medium light gray; clast size ranges from medium upper to fine upper; sub round; moderate developed sphericity; moderate sorting; pitted to impacted texture; mature nature; non to very weak siliceous cement; slight hydrophilic clay matrix; dominant grain support; composed of 80% quartz, 20% metalithics, chert, tuff, greenstone. Tuffaceous claystone (2270' to 2310') = moderate yellowish brown; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; slimy; non to slight cohesive; slight to moderate adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal texture; massive beds of tuffaceous clay composed of 80% clay, 20% silt. Tuffaceous siltstone (2320' to 2370') = medium light gray to light brownish gray; poor to moderate indurated; brittle in parts; slightly crumbly; lumpy to clumpy; clotted to clustered; mushy to pasty; non to slight cohesive; slightly adhesive; amorphous to earthy fracture; massive to sub nodular habit; dull earthy luster; silty to clayey to colloidal texture; massive gradational silt and clay beds interbedded with sands. Tuffaceous claystone (2380' to 2340') = light brownish gray; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky to slimy; non to slight cohesive; slight adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal texture; massive beds of homogeneous clay. Sand (2350' to 2420') = medium light gray; clast size range coarse lower to silt; sub round; moderate developed sphericity; very poor sorting; pitted to impacted texture; sub mature; non to very weak siliceous cement; moderate silt I clay matrix; dominant matrix support with secondary grain support in parts; [:I El~OCH 12 I I I UNOCALe Happy Valley #10 composed of 90% quartz, 10% metalithics, greenstone, and various lithic fragments; fair to poor porosity and permeability; no oil indicators. Tuffaceous claystone (2430' to 2550') = light gray; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky; slimy; non to slight cohesive; moderate adhesive; amorphous fracture; massive habit; moderate earthy luster; clayey to colloidal texture; massive beds of clay interbedded with fine to medium grain sands. Sand (2560' to 2610') = light gray; clast size ranges from medium upper to very fine lower; sub round to rounded; moderate to well developed sphericity; poor becoming moderate sorting @ 2490'; polished and impacted texture; sub mature; non to very weak siliceous cement; slight soluble clay matrix; dominant grain support; composed of 90% quartz, 10% various lithic fragments; fair to good porosity and permeability; no oil indicators. Sandlsandstone (2620' to 2670') = light gray; clast size ranges from medium upper to very fine upper; sub round; moderate to well developed sphericity; moderate to poor sorting; pitted to impacted texture; sub mature nature; non to very slight siliceous cement; slight to moderate hydrophilic clay matrix; grain supported with secondary matrix support at 2550'; composed of >90% quartz; fair to good porosity and permeability; no oil indicators. Tuffaceous claystone (2680' to 2730') = pale yellowish brown; very soft; lumpy to clumpy; clustered to clotted; gelatin mushy to pasty; tacky to slimy; non to slight cohesiveness; moderate adhesive; amorphous fracture; massive habit; dull earthy luster; colloidal to clayey text; massive gradational beds of clay/silt. Carbonaceous shalelcoal (2700' to 2750')black some mottled brownish black; brittle to firm; earthy luster in carbonaceous shale to resinous in coal; matte texture dominant planar fracture in carbon shale to hackly in coal; abundant visible bleeding gas from cuttings; cuttings very ground up: small in size. Tuffaceous claystone (2790' to 2880') = medium gray, very soft; malleable; sectile; flexible; elastic; lumpy to clumpy clustered to clotted; gelatinous; mushy to pasty; tacky to slimy; non to slight cohesive; moderate to very adhesive; amorphous to earthy fracture; massive habit; moderate to dull earthy luster; clayey to colloidal texture; massive bed of clay composed of 80% clay, 20% silt; scattered fine grained sands. Carbonaceous shale/coal (2890' to 2940')black to grayish black; firm to brittle; resinous in coal laminae to matte in carbon shale; sub blocky to planar fracture in carbon shale; composed of very carbonaceous shale with thin beds of lignitic to sub bituminous coal grading very carbonaceous shale; visible bleeding gas from larger cuttings. Tuffaceous claystone (2950' to 3000') = medium gray; very soft to soft; slightly malleable to seetile; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; tacky; non to slight cohesive; moderately adhesive; amorphous to earthy fracture; massive habit; dull earthy luster; clayey to colloidal texture; massive gradational beds of clay and thin beds to laminae of very carbon shale; scattered fine sands. Sand (3015' to 3065') = medium to light gray; clast size ranges from medium lower to very fine; sub round; moderate to well developed sphericity; poor sorting; polished to impacted texture; sub mature; non to very slight siliceous cement; abundant clay/silt matrix; dominant matrix support; occurs as interbedded sands to thin beds; poor porosity and permeability; no oil indicators. Carbonaceous shale (3070' to 3120') = black to grayish black; brittle to firm; earthy luster; matte texture; planar fracture along shale partings; composed of very carbonaceous shale in thin to laminae beds; slight visible bleeding gas from larger cuttings. Tuffaceous claystone (3130' to 3150') = medium gray; very soft to soft; slightly malleable to sectile; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; tacky to slimy; non to slight cohesive; slight to ~ EPOCH 13 . . , UNOCALe Happy Valley #10 moderate adhesive; amorphous to earthy fracture; massive habit; dull earthy luster; clayey to colloidal texture; massive gradational beds of clay, silt, carbon and fine sand. Sand (3155' to 3290') = medium light clast size ranges from medium lower to very fine; moderate to well developed sphericity; polished to pitted texture; poor sorting; sub mature nature; non to very weak siliceous cement; dominant clay matrix and support; composed of 90% quartz, 10% various lithic fragments; poor porosity and permeability; occurs as interbedded sands and thin beds; no oil indicators. Carbonaceous shalelcoal (3300' to 3250') = black to brownish black; brittle to firm; earthy to resinous luster; matte to smooth texture in coals; overall hackly fracture with some planar; composed of lignitic to very carbonaceous shale. Sand (3260' to 3320') = medium gray; clast size range from coarse lower to fine lower; sub round to rounded; well developed sphericity; poor sorting; polished to pitted texture; sub mature to some mature nature; non to very weak siliceous cement; moderate claylsilt matrix; both grain and matrix support; composed of 50% quartz, 40% dark gray metalithics10% chert and various lithic fragments; fair to poor porosity and permeability. Tuffaceous claystone (3330' to 3370') = light brownish gray; very soft; lumpy to clumpy clustered to clotted; gelatinous; mushy to pasty; tacky to slimy; non to slight cohesiveness; moderate to very adhesive; massive habit; dull earthy luster; colloidal texture; massive bed of soluble clay with minor carbon shale. Sand (3380' to 3430') = light gray; clast size ranges from medium upper to fine lower; sub angular to sub round; moderate sphericity; moderate sorting; chip to impacted texture; immature; non to very slight siliceous cement; moderate to abundant clay matrix; matrix supported; poor porosity and permeability; no oil indicators. Sand (3440' to 3480') = light gray to medium gray; clast size ranges from coarse grain to fine upper; sub round; moderate to well developed sphericity; moderate to poor sorting; polished to impacted texture; immature nature; non to very slight siliceous cement; moderate to abundant silt/clay matrix; dominant matrix support with some grain support in parts; poor porosity and permeability very detritalish; no oil indicators. Tuffaceous siltstone (3490' to 3510') = medium gray; poorly indurated; lumpy to clumpy; clustered to clotted; gelatinous mushy to pasty; tacky to slimy; non to slight cohesive; slight to moderate adhesive; amorphous fracture; massive habit; dull earthy luster; silty to clay to colloidal texture; massive beds of silt, clay and sand; reworked and very detritalish. Sand (3520' to 3570') = medium gray; clast size ranges from coarse lower to fine upper becoming coarse upper to pebble at 3575'; sub round to rounded; well developed sphericity in medium to fine grains; moderate to poor sorting; pitted to polished texture; sub mature; non to very slight siliceous cement; abundant clay matrix; dominant matrix support: very hydrophilic; composed of 50% quartz, 50%dark gray metalithics; poor porosity and permeability; conglomerate bed at 3575';no oil indicators. Sand (3580' to 3660') = light gray; clast size ranges from medium upper to fine lower; some conglomerate scattered at 3650'; sub round to rounded; moderate to well developed sphericity; moderate sorting; polished to pitted texture; sub mature nature; non to very slight siliceous cement; dominant clay and silt matrix; very hydrophilic; dominant matrix supported; some grain support in parts; composed of 60% quartz, 30% dark gray metalithics, 10% various lithic fragments; poor porosity and permeability; very detritalish and dirty appearance; no oil indicators. Coal (3680' to 3715') = black to dusky brown; firm to moderately hard; crumbly to tough; commonly crunchy and brittle; tabular, blocky and irregular cuttings habit; slightly resinous luster; smooth texture; rare thin tuffaceous claystone laminations. ~ EIJOCH 14 I I I UNOCALe Happy Valley #10 Sand (3715' to 3800') = light to medium gray overall with slight greenish hues; clasts range from very fine lower to coarse lower, dominantly fine to medium grains; angular to rounded, dominantly subangular to subround; poorly sorted overall, moderately well sorted in the fine to medium range; composed of 40% quartz, 60% metamorphic lithics, common black mafic grains; unconsolidated in samples ;clay matrix inferred; moderate acid reaction from thin crusts of calcite on grain surfaces; estimated fair porosity and permeability; no oil indicators noted. Tuffaceous siltstone (3800' to 3860') = light to medium gray; soft to firm; crumbly to moderately tough; subblocky and irregular shaped cuttings; matte luster with scattered sparkles; gritty, abrasive texture; moderately calcareous; scattered to common very fine sand grains throughout; argillaceous, grading to and interbedded with claystone. Tuffaceous claystone (3860' to 3940') = medium light gray to light brownish gray to occasionally bluish gray; soft and soluble to moderately soluble; smooth to gritty texture with floating mostly very fine to medium lower grains with slightly scattered coarse; grading matrix supported sandstone; some grading to very find sandy siltstone; non to variably organic often with slight micro partings of carbonaceous matter, to grading grayish brown carbonaceous shale with increased organics and partings. Sand (3860' to 4010') = medium gray overall; very fine to medium and scattered coarse grains; subangular; poorly sorted; mostly included in claystone to locally grading matrix supported sandstone; 70% quartz dominating finer fraction, and 30% gray to black to brown grains more common in coarser fraction; estimate some very poor porosity. Tuffaceous siltstone (4010' to 4040') = light to medium gray; soft to firm; crumbly to rarely moderately tough; subblocky and irregular shaped cuttings; earthy luster with scattered sparkles; grainy, gritty texture; moderately calcareous; scattered to common very fine sand grains throughout; argillaceous, grading to and interbedded with claystone; also interbedded with black to dusky brown coal. Sand/sandstone (4050' to 4140') = medium gray overall; friable when consolidated; clasts range from very fine lower to coarse lower, mostly fine to medium grain; angular to rounded, dominantly subangular to subround; poorly sorted overall; 40% quartz, 60% metamorphic lithics; silty clay matrix; moderate calcite cement; variable matrix/grain supported; estimated poor to fair porosity and permeability. Coal (4130' to 4165') = black to dusky brown; firm to moderately hard; crunchy to brittle and moderately tough; variable clean to argillaceous; tabular and blocky cuttings; slightly resinous luster; interbedded with tuffaceous claystone. Tuffaceous claystone (4170 to 4210') = light gray, occasionally with moderate brown hues; very soft to soft, occasionally moderately firm; mostly appears as clay with common slightly firm lumps; occasionally as poorly to fairly indurated cuttings; matte, earthy luster; smooth to moderately silty texture; common carbonaceous specks and streaks; locally very carbonaceous, grading in part to carbonaceous shale. Carbonaceous shale (4220' to 4265') = black, brownish black; firm to moderately hard; brittle to tough; tabular and blocky cuttings; dull to occasionally slightly shiny luster; smooth to moderately grainy texture; non calcareous; variable carbonaceous content; scattered thin laminations of tuffaceous claystone. Sand (4265' to 4325') = multicolored, dominantly light to medium gray, light to medium greenish gray, clear, black; clasts range from very fine lower to coarse lower, dominantly fine to medium grain; angular to rounded, poorly sorted overall, moderately sorted in the fine to medium range; composed of 60% metamorphic lithics, 40% quartz, common mafic minerals; clay matrix inferred; estimated poor porosity and permeability. Sand (4325' to 4400') = multicolored, dominantly light to medium gray, light to medium greenish gray, clear, black; clasts range from very fine lower to coarse lower, dominantly fine to medium grain; angular to rounded, poorly sorted overall, moderately sorted in the fine to medium range; composed of 60% ~ El~()CH 15 I I I UNOCALe Happy Valley #10 metamorphic lithics, 40% quartz, common mafic minerals; clay matrix inferred; unconsolidated in samples; vigorous acid reaction; estimated poor to fair porosity and permeability. Tuffaceous claystone (4410 to 4460') = light gray, occasionally with brownish gray hues; very soft to soft, occasionally moderately firm; mostly appears as clay with common slightly firm lumps; occasionally as roughly formed subblocky cuttings; matte, earthy luster; smooth to moderately grainy texture; common carbonaceous specks and streaks; occasionally with thin coal seams. Sand (4540' to 4600') = medium gray overall; very fine upper to medium lower to scattered coarse to trace very coarse and pebble; subangular overall; moderately to poorly sorted; estimate mostly grain supported; 60% quartz, and 40% gray to dark gray to dark brownish gray mostly silicates including mostly metalithics and some siliceous lithics and chert; probably interbedded with tuffaceous claystone and some carbonaceous shale; to locally interbedded coal; estimate mostly poor to some fair porosity and permeability. Tuffaceous claystone (4620' to 4685') = light gray to medium gray, occasionally with slight brownish hues; very soft to rarely moderately firm; mostly appears as clay with common slightly firm lumps; easily hydrated; slightly expansive; firmer fraction is subblocky with rounded edges; matte luster; smooth to moderately grainy texture; non calcareous; locally silty; common carbonaceous streaks and specks; locally grades to carbonaceous shale; few thin coal seams. Sand (4690' to 4750') = light gray overall; dominantly light to medium gray, clear, milky white, light to medium greenish gray; clasts range from very fine lower to medium upper, mostly fine lower to medium lower; angular to rounded, dominantly angular to subround; poor to moderate sorting; composed of 70% quartz, 30% metamorphic lithics, scattered to common black mafic minerals; clay matrix inferred; no acid reaction; estimated poor to fair porosity and permeability. Carbonaceous shale (4760' to 4800') = black to dusky brownish black; firm to occasionally moderately hard; 1 to 2 mm cuttings with common platy habit; matte to occasionally slightly shiny luster; smooth texture; non calcareous; rare light gray and moderate brown laminations; thinly interbedded with tuffaceous claystone. Tuffaceous claystone (4810' to 4870') = light gray to medium gray, commonly with slight brownish hues; very soft to rarely moderately firm; dominantly appears as clay with common mod firm lumps; easily hydrated; slightly expansive; firmer fraction is subblocky with rounded edges; dull luster; smooth to moderately silty texture; non calcareous; locally silty; common carbonaceous streaks and specks; locally grades to carbonaceous shale; occasional thin coal seams. Coal (4895' to 4930') = black to dusky brown; firm to moderately hard; crunchy to brittle and moderately tough; variable clean to argillaceous; tabular and blocky cuttings; slightly resinous luster; interbedded with tuffaceous claystone. Tuffaceuos claystone (4925' to 4990') = medium light gray to medium gray; mostly soft and soluble; to some slightly firm to firm and calcareous; some sandy especially calcareous and grading calcareous tuff; possible interbedded sandstone likely mostly matrix supported and variably calcareous; interbedded coal and coal laminations grading carbonaceous shale. Tuffaceous claystone (4990' to 5040') = medium gray to light gray; soft to moderately soft and soluble; some sandy to possible interbedded sandstone likely matrix supported; occasionally grading ash fall tuff; some thinly interbedded coal, to interlaminated coal and carbonaceous partings often interlaminated with variably organic brownish clays and grading carbonaceous shale. Sand (5035' to 5085') = medium gray overall; very fine to medium, especially fine to medium lower, and scattered coarse; subangular to subrounded; estimate moderately to poorly sorted and probably mostly grain supported with ashy clay matrix; 60% quartz, and 40% dark gray to gray silicates, mostly metalithics, and some partially siliceous lithics; estimate some fair porosity; no oil indicators. ~ El~OC·H 16 I I I UNOCALe Happy Valley #10 Tuffaceous claystone (5070' to 5170') = medium gray to medium light gray to some medium dark gray; moderately soft to soft and soluble, to some slightly firm to firm and calcareous grading tuffaceous shale; some slightly carbonaceous with disseminated carbonaceous clays to flakes and partings of carbonaceous matter, locally increasing grading to carbonaceous shale; some sandy with possible thinly interbedded sandstone and sandy calcareous tuff. Sand (5115' to 5240') = medium gray overall; very fine to medium, especially very fine upper to medium lower, and trace coarse; subangular to subrounded; estimate moderately to poorly sorted and grain and matrix supported with ashy clay matrix; thinly interbedded in various lithologies; 60% quartz, and 40%dark gray to gray silicates, mostly metalithics, and some partially siliceous lithics and calcareous matter; locally grading sandy calcareous tuff; estimate some poor to fair porosity; no oil indicators. Tuffaceous claystone (5170' to 5310') = medium gray to medium light gray to some medium dark gray; moderately soft to soft and soluble, to some firm to very firm and calcareous and grading to tuffaceous shale; some slightly carbonaceous with disseminated carbonaceous clays to flakes and partings of carbonaceous matter, locally increasing grading to carbonaceous shale; some sandy with possible thinly interbedded sandstone and slightly sandy calcareous tuff. Tuffaceous claystone (5310' to 5430') = medium gray to medium dark gray to brownish gray to medium light gray; moderately soft to soft and soluble, to occasionally firm and calcareous grading to tuffaceous shale; some variably organic with disseminated carbonaceous matter and brownish organic clay, locally grading carbonaceous shale with flakes and partings of carbonaceous matter and thinly interbedded coal; locally sandy with possible interbedded sandstone. Coal (5350' to 5420') = grayish black to brownish black; irregular platy to flaky to angular fracture; common visible laminations; lignite to subbituminous; mostly thinly bedded in tuffaceous and non to some variably organic claystone. Sand (5410' to 5470') = medium dark gray to medium gray; very fine to medium grains with slight coarsening downward; subangular to subrounded; estimate poorly to moderately sorted in ashy clay matrix and matrix and grain supported grading to and interbedded with tuffaceous claystone and minor carbonaceous shale and coal; 60% quartz, and 40% very dark gray to gray mostly silicates, including metalithics; estimate some poor to possible fair porosity; no oil indicators. Sand (5470' to 5550') = medium dark gray overall; fine to very coarse and slightly scattered pebble, especially fine upper to coarse lower; subrounded to subangular; moderately well to some poorly sorted; 50% quartz, and 50% very dark gray to gray mostly silicates, including metalithics, and minor partially siliceous lithics; estimate fair to poor porosity overall; no oil indicators. Tuffaceous claystone (5550' to 5610') = medium gray to medium light gray to light brownish gray; soft to moderately soft and soluble, to some slightly firm to firm and calcareous; often slight to moderate disseminated carbonaceous matter, to common flakes and partings in variably organic claystone, grading to carbonaceous shale and with thinly interbedded coal; some sandy with possible thinly interbedded sandstone. Tuffaceous claystone (5610' to 5660') = medium light gray to medium dark gray to light brownish gray; soft to moderately soft and soluble, to rare slightly firm to firm and calcareous; often slight to moderate disseminated carbonaceous matter, to common flakes and partings in variably organic claystone, grading to carbonaceous shale and with thinly interbedded coal; some sandy with possible thinly interbedded sandstone. Coal (5550' to 5740') = grayish black to brownish black; slightly malleable to firm and brittle; subplaty to flaky to angular fracture; common visible lamina; lignite to some subbitminous; thin beds and laminations in tuffaceous claystone and variably organiclcarbonaceous claystone and shale. ~ EI'OCH 17 UNOCALe Happy Valley #10 · Tuffaceous claystone (5660' to 5760') = medium light gray to medium dark gray to light brownish gray; soft to moderately soft and soluble, to some slightly firm to firm and calcareous; often slight to moderate disseminated carbonaceous matter, to common flakes and partings in variably organic claystone, occasionally grading to carbonaceous shale and with interbedded coal; some sandy and calcareous grains occasionally grading to sandstone and calcareous tuff. Tuffaceous claystone (5760' to 5830') = medium light gray to occasionally medium dark gray; soft to moderately soft and soluble, to some slightly firm to firm and calcareous; often slight to some moderate disseminated carbonaceous matter, to common flakes and partings, occasionally grading to carbonaceous shale with thinly interlaminated to thin interbedded coal; some sandy and calcareous grains occasionally grading to sandstone and calcareous tuff; sand mostly very fine to fine to locally some medium grains. Tuffaceous claystone (5760' to 5830') = medium light gray to occasionally medium dark gray; soft to moderately soft and soluble, to rare slightly firm to firm and calcareous; often slight to some moderate disseminated carbonaceous matter, to common flakes and partings, occasionally grading to carbonaceous shale with thinly interlaminated to thin interbedded coal; some sandy and calcareous grains occasionally grading to sandstone and calcareous tuff. Sand (5910 to 5980') = light to medium gray overall; mostly light gray, milky white, medium to dark gray, black; clasts range from very fine to coarse, dominantly very fine upper to fine upper; angular to rounded, dominantly angular to subangular; poor to moderate sorting; composed of 70% quartz, 30% metamorphic lithics, common mafic minerals; appears loose in samples; clay matrix inferred; no acid reaction; estimated poor to fair porosity and permeability; thin stringers in massive tuffaceous claystone section. · Coal (5990' to 6040') = black to dusky brownish black; firm to moderately hard; brittle to moderately tough; dull to slightly resinous luster; smooth to slightly rough surface texture; variable argillaceous content; some grades to carbonaceous shale; "cleaner" fraction is more resinous appearing; "dirty" fraction is dull with more brownish hues; scattered thin laminations of tuffaceous claystone. Tuffaceous claystone (6050' to 6110') = light gray with occasional brownish and greenish hues; very soft to rarely slightly firm; amorphous clay lumps; rarely as mushy to crumbly poorly indurated irregularly shaped cuttings; matte, earthy luster; smooth to mod silty texture; dominantly non calcareous, occasionally moderate to strong acid reaction; common carbonaceous specks and streaks. Sand (6110' to 6150') = medium gray to medium dark gray; very fine upper to medium lower, to scattered medium upper and trace coarse; subangular; poorly to moderately sorted and estimate mostly matrix and some grain supported in ashy clay; 60% quartz, and 40% dark gray to gray to trace green mostly silicates, including metalithics and some partially siliceous lithics; estimate mostly very poor to poor and possible fair porosity; no oil indicated. Coal (6100' to 6240') = black to some brownish black; very firm and brittle with angular to sub platy fracture and common visible lamina, to some crunchy to malleable with increasing clay content; subbituminous grading to lignite; thinly bedded to laminated in tuffaceous claystone, some variably organic with common flakes, partings, and disseminated carbonaceous matter grading carbonaceous shale. Tuffaceous claystone (6150' to 6300') = medium light gray, to medium gray some with faint brownish hue, to occasionally brownish gray; soft and soluble to slightly firm and slightly soluble; occasionally locally firm to very firm and calcareous grading tuffaceous shale; often slightly organic in firmer darker clays with disseminated carbonaceous clays and matter; often with slight to moderate flakes and locally partings of carbonaceous matter in variably organic clays and grading to carbonaceous shale. · Sand (6310' to 6340') = medium gray to medium dark gray; very fine upper to medium lower, and trace medium to coarse; subangular; estimate poorly to moderately sorted and mostly matrix supported; ~ EI'()CH 18 UNOCALe Happy Valley #10 . associated with some dense sandy calcareous tuff; 50% quartz and 50% very dark gray to gray silicates including metalithics, and some partially siliceous lithics; estimate mostly very poor to poor porosity. Tuffaceous claystone (6300' to 6450') = medium gray some with faint brownish hue to medium light gray, to occasionally brownish gray; soft and soluble to slightly firm and slightly soluble; some locally firm to very firm and calcareous grading tuffaceous shale to sandy tuff; often slightly organic in firmer darker clays with disseminated carbonaceous clays and matter; often with slight to moderate flakes and locally partings of carbonaceous matter in variably organic clays and grading to carbonaceous shale. Tuffaceous claystone (6450' to 6540') = medium gray often with faint brownish hue to medium light gray to rare brownish gray; moderately soft to soft and hydrophilic, occasionally slightly firm; earthy to clayey texture; mostly slightly organic with disseminated carbonaceous clay and matter; often slight to moderate flakes and locally partings of carbonaceous matter in slight to occasionally variably organic clays; occasionally grading to carbonaceous shale and some interbedded coal. Coal (6520 to 6580') = black to brownish black to occasionally dusky brown; very firm and brittle and subplaty to angular and dense often with visible lamina; to slightly firm and crunchy to flaky with increasing clay and variably organic clay partings; interbedded in tuffaceous claystone and ash, and interbedded with and grading to carbonaceous shale; subbituminous to lignite. Tuffaceous claystone (6540' to 6650') = medium light gray to medium gray, some with brownish hue to occasionally brownish gray; soft and soluble to slightly firm and slightly soluble; rare locally firm to very firm and calcareous grading tuffaceous shale; often slightly organic in firmer darker clays with disseminated carbonaceous clays and matter; often with slight to moderate flakes and partings of carbonaceous matter in variably organic clays and grading to carbonaceous shale. . Sand (6595' to 6645') = medium gray to medium dark gray; very fine to medium lower, and trace medium to coarse; subangular; estimate poorly sorted and mostly matrix supported, and some sandy claystone; associated with some dense sandy calcareous tuff; 50% quartz, and 50% very dark gray to gray silicates including metalithics, and some partially siliceous lithics; estimate very poor to poor porosity. Coal (6600' to 6780') = black to brownish black to dusky brown; slightly firm and flaky to crunchy, to very firm and dense with subplaty to angular fracture; occurs and laminations and interbedded in tuffaceous claystone, carbonaceous shale, and ash; lignite to subbituminous. Tuffaceous claystone (6645' to 6820') = medium light gray to medium gray, some with brownish hue to some medium dark gray to brownish gray; moderately soft to soft and hydrophilic; clayey to earthy to silty texture; occasionally grading ash fall tuff; often with disseminated carbonaceous clay and matter; often slight to moderate flakes and locally partings of carbonaceous matter in slight to variably organic clays; occasionally grading to carbonaceous shale, and with interbedded to interlaminated coal; occasionally sandy with fine to medium lower grains; occasional calcareous tuffaceous shale. Coal (6800' to 6930') = black to brownish black to dusky brown; slightly firm and flaky to crunchy, to very firm and dense with subplaty to angular fracture; occurs as laminations and interbedded in tuffaceous claystone and carbonaceous shale; lignite to subbituminous. Tuffaceous claystone (6645' to 6820') = medium gray, some with brownish hue, to medium light gray; soft to moderately soft and hydrophilic; clayey to earthy to slightly silty texture; often with disseminated carbonaceous clay and fines, flakes, and partings of carbonaceous matter; occasionally grading carbonaceous shale and with interbedded coal; slight interbedded sand and associated sandy calcareous tuff. . Tuffaceous claystone (6940' to 6990') = light gray to medium gray, occasional slightly brownish hues; very soft; appears as clay in samples; very soluble; moderately expansive with hydration; rarely appears as roughly formed subblocky cuttings; matte luster; smooth to moderately grainy texture; mostly non calcareous, occasionally moderately to very calcareous; common thin coal laminations and seams. [:I E,I'OCH 19 . . . UNOCALe Happy Valley #10 Coal (7005' to 7070') = black, dark to dusky brown, brownish black; firm to moderately hard; crunchy to moderately tough; platy and tabular cuttings; matte to slightly resinous luster; smooth to moderately rough surface texture; occasional thin laminations of tuffaceous claystone; appears to be mostly less than 1 foot seams scattered throughout massive tuffaceous claystone section; occasionally as 5 to 10 foot seams; commonly argillaceous, grading to and interbedded with carbonaceous shale. Sand (7080' to 7130') = light to medium gray overall; clasts range from very fine lower to medium upper, mostly fine upper medium lower; angular to subround; moderately sorted; composed of 50% quartz, 50% metamorphic lithics; scattered to common black mafics; clay matrix inferred; vigorous acid reaction; estimated poor to fair porosity and permeability. Tuffaceous claystone (7145' to 7200') = light gray to medium gray, occasional brownish and greenish hues; very soft to rarely moderately firm; mostly appears as lumpy clay, occasionally as subblocky moderately firm cuttings; matte, earthy luster; smooth to grainy texture; calcareous; locally common very fine to medium sand grains; common coal laminations and seams. Sand (7200' to 7260') = very light gray overall; dominantly clear, milky white, light to medium gray; occasionally medium greenish gray, common black; clasts range from very fine lower to coarse lower, angular to subround; moderately sorted in the fine to medium range; composed ofBO% quartz, 20% metamorphic lithics, scattered black mafic minerals; loose in samples, clay matrix inferred; non to very slightly calcareous; estimated fair porosity and permeability. Coal (7265' to 7300') = black to brownish black to dusky brown; moderately firm and flaky to crunchy, occasionally mod hard and dense with subplaty to angular fracture; occurs as laminations and interbedded in tuffaceous claystone and carbonaceous shale; lignite to subbituminous. Sand (7310' to 7360') = very light gray overall; grains are mostly milky white, light to medium gray, clear, occasionally light to medium greenish gray, occasionally black; clasts range from very fine lower to medium upper, dominantly fine range; angular to rounded, mostly subangular to subround; moderately well sorted; composed of 80 to 90% quartz, 10 to 20 % metamorphic lithics; scattered black mafic minerals; estimated fair porosity and permeability. Tuffaceous claystone (7380' to 7430') = light gray to medium gray, occasional brownish and greenish hues; very soft to rarely moderately firm; amorphous lumps dominate, occasionally appears as subblocky moderately firm cuttings; dull, earthy luster; smooth to grainy texture; non to slightly calcareous; locally silty, grades in part to tuffaceous siltstone; common coal streaks and laminations. Sand (7440' to 7520') = very light gray to light gray overall with slight "peppered" appearance; clear, light to medium gray, milky white, occasionally light to medium greenish gray, occasionally black; clasts range from very fine lower to medium lower, dominantly fine range; angular to subround; moderately well sorted; composed of 90% quartz, 10% metamorphic lithics, scattered mafic minerals; loose in samples; clay matrix inferred; estimated poor to fair porosity in the upper part of the zone, estimated fair to good porosity in the lower part of the zone. Sand (7540' to 7590') = medium light gray to some brownish hue in basal part of sand; very fine to coarse, especially medium to fine; moderately high to some low sphericity; subrounded to subangular; moderately well to moderately sorted and mostly grain supported with slight to moderate ashy clay matrix and traces of calcite frosting on grains; some organic clay matrix at base grading to variably organic tuffaceous claystone, carbonaceous shale, and coal; 80% quartz, and 20% very dark gray to gray to black to trace green mostly silicates including metalithics, and minor coal and clay lithic; estimate fair to poor porosity and permeability; no oil indicators. Sandstone/siltstone (7610' to 7680') = light brownish gray to medium light gray with brownish hue; mostly very fine grained to silty to locally very fine to medium; subangular; grain and matrix supported in slightly to moderately organic clay matrix; often grading to claystone; very poor visible porosity. ~ El)()C·H 20 UNOCALe Happy Valley #10 · Sand (7680' to 7715') = medium light gray some with brownish hue; medium to fine grains; subangular to subrounded; moderate to high sphericity; moderately sorted overall; estimate mostly grain supported with slight overall clay matrix and traces of calcite; 80% quartz and 20% mostly meta lithic silicates and minor coal and clay grains; estimate some fair porosity; no oil indicators. Tuffaceous claystone (7715' to 7820') = light brownish gray to medium light gray to medium gray to brownish gray to grayish brown to medium dark gray; mostly soft and soluble to some slightly firm; clayey to slightly silty/sandy texture; locally grading fine to medium sand; mostly slightly organic; often with very slight carbonaceous silts and fines; locally variably organic with fines, flakes, and partings of carbonaceous matter and associated with interbedded coal. Sand (7860' to 7920') = light gray overall; mostly clear, milky white, light to medium gray, occasionally light to medium greenish gray, occasionally black; clasts range from very fine lower to coarse lower, mostly fine lower to medium lower; angular to subround; moderately sorted; composed of 80% quartz, 20% metamorphic lithics; scattered black mafic minerals; ashy appearing; estimated fair porosity and permeability. Tuffaceous claystone (7925' to 7980') = light gray to medium gray, occasional brownish and greenish hues; very soft to rarely moderately firm; mostly lumpy clay, occasionally appears as subblocky moderately firm cuttings; dull, earthy luster; smooth to gritty texture; non to slightly calcareous; locally silty, grades in part to tuffaceous siltstone; common coal streaks and laminations. · Coal (7985' to 8020') = black, dusky brown, brownish black; firm to moderately hard; crunchy to occasionally tough; tabular, platy and irregular cuttings; matte to slightly resinous luster; smooth texture; interbedded with tuffaceous claystone; occasional pinpoint gas bubbles on fresh fracture surfaces; locally argillaceous, grading in part to carbonaceous shale. Tuffaceous siltstone (8040' to 8110') = light gray with slight brownish hues; soft to firm, occasionally moderately hard; crumbly to occasionally moderately tough; irregular, subblocky and blocky cuttings with mostly rounded edges; earthy luster with scattered sparkles; gritty, sucrosic appearing texture; moderately to occasionally very calcareous; common carbonaceous specks and streaks; argillaceous, grading to and interbedded with tuffaceous claystone; common very fine to fine sand grains embedded throughout. Tuffaceous claystone (8120' to 8165') = light to medium gray, rarely with slight brownish hues; very soft; mostly appears as thick clay with common slightly firm lumps; mushy to occasionally slightly firm; easily soluble in water; moderately expansive; locally silty, grading in part to siltstone; common carbonaceous streaks; ashy appearing; locally very calcareous. Sand (8185' to 8240') = light gray overall; clasts range from very fine lower to coarse lower, mostly fine grain; angular to rounded, mostly subangular to subround; moderately sorted; composed of 80% quartz, 20% metamorphic lithics; scattered mafic minerals; totally loose in samples; slight acid reaction; upper zone ashy and argillaceous; lower zone is cleaner; estimated fair to good porosity and permeability; no oil indicators. Tuffaceous claystone (8240' to 8300') = light brownish gray, light gray; very soft to soft, rarely slightly firm; mushy to rarely slightly brittle; mostly appears as clay with common lumps; occasionally as roughly formed poorly indurated cuttings; matte luster smooth to moderately gritty texture; non to locally slightly calcareous; locally silty, grades in part to siltstone. · Sand/sandstone (8300' to 8335') = medium light gray some with brownish hue, to light brownish gray; very fine to medium grains; subangular to locally subrounded; moderately high sphericity; poorly to moderately sorted and mostly grain supported in ashy to slightly organic clay matrix; streaks moderately consolidated calcareous sandstone; 80% quartz, and 20% dark gray to brownish black to gray lithics [:I El-"()C·H 21 · · · UNOCALe Happy Valley #10 including mostly silicates and some partially siliceous lithics; estimate mostly poor to possible streaks fair porosity; no oil indicators. Tuffaceous claystone (8335' to 8400') = medium light gray to medium gray, mostly with brownish hue, to light brownish gray; moderately soft to soft, clayey to slightly siltylfine sandy texture; variably organic and carbonaceous with interbedded coal and fine sandstone. [;1 ET)OCH 22 UNOCALe Happy Valley #10 SURVEYS Survey Inclin- Course True Vertical Coordinates Closure Dogleg Build Walk Vertical Depth ation Azimuth Length Depth Section N/S ENV Distance Angle Severity Rate Rate (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (d/100') (d/100') (d/100') 0 0.00 0.00 0 0 0.00 0.00 S 0.00 W 0.00 180.00 176 0.59 320.92 176 176.00 0.88 0.70 N 0.57 W 0.91 320.92 0.34 0.34 182.34 238 0.67 328.53 62 237.99 1.53 1.26 N 0.96 W 1.59 322.65 0.19 0.13 12.27 300 1.57 319.72 62 299.98 2.70 2.22 N 1.70 W 2.79 322.52 1.47 1.45 -14.21 361 2.68 316.08 61 360.94 4.94 3.88 N 3.23 W 5.05 320.24 1.83 1.82 -5.97 423 3.91 316.42 62 422.83 8.46 6.46 N 5.69 W 8.61 318.60 1.98 1.98 0.55 485 6.34 313.07 62 484.58 13.96 10.33 N 9.65 W 14.13 316.94 3.95 3.92 -5.40 547 8.89 309.20 62 546.03 22.16 15.69 N 15.87 W 22.32 314.69 4.19 4.11 -6.24 608 11.46 306.68 61 606.07 32.94 22.29 N 24.38 W 33.04 312.44 4.27 4.21 -4.13 671 13.85 308.49 63 667.53 46.74 30.73 N 35.30 W 46.80 311.04 3.85 3.79 2.87 733 15.75 310.46 62 727.47 62.56 40.81 N 47.51 W 62.63 310.66 3.17 3.06 3.18 796 16.96 310.40 63 787.92 80.29 52.31 N 61.02 W 80.37 310.61 1.92 1.92 -0.10 859 18.49 308.66 63 847.93 99.46 64.51 N 75.82 W 99.55 310.39 2.57 2.43 -2.76 890 19.17 307.72 31 877.27 109.46 70.69 N 83.68 W 109.54 310.19 2.40 2.19 -3.03 1037 26.62 305.74 147 1012.60 166.59 104.74 N 129.57 W 166.61 308.95 5.09 5.07 -1.35 1131 28.40 305.11 94 1095.96 209.96 129.90 N 164.95 W 209.96 308.22 1.92 1.89 -0.67 1226 32.20 306.62 95 1177.97 257.85 158.01 N 203.76 W 257.85 307.79 4.08 4.00 1.59 1289 33.56 306.81 63 1230.88 292.04 178.45 N 231.18 W 292.04 307.67 2.16 2.16 0.30 1352 34.88 306.71 63 1282.97 327.46 199.66 N 259.56 W 327.47 307.57 2.10 2.10 -0.16 1415 36.80 308.07 63 1334.04 364.34 222.06 N 288.86 W 364.35 307.55 3.30 3.05 2.16 1478 39.38 309.13 63 1383.62 403.20 246.31 N 319.23 W 403.21 307.65 4.22 4.10 1.68 1541 42.13 308.61 63 1431.34 444.32 272.12 N 351.25 W 444.32 307.77 4.40 4.37 -0.83 1604 44.00 308.67 63 1477.37 487.33 298.98 N 384.85 W 487.33 307.84 2.97 2.97 0.10 . [:I r~l)()(:H . . UNOCALe Happy Valley #10 1667 45.74 307.99 63 1522.01 531.78 326.54 N 419.71 W 531.78 307.88 2.86 2.76 -1.08 1730 46.65 308.27 63 1565.62 577.24 354.61 N 455.48 W 577.24 307.90 1.48 1.44 0.44 1794 46.40 308.32 64 1609.66 623.69 383.39 N 491.93 W 623.69 307.93 0.39 -0.39 0.08 1857 47.78 308.10 63 1652.55 669.83 411.93 N 528.18 W 669.83 307.95 2.21 2.19 -0.35 1920 49.17 308.56 63 1694.31 716.99 441.19 N 565.18 W 716.99 307.98 2.27 2.21 0.73 2046 48.68 308.25 126 1777. 1 0 811.97 500.19 N 639.61 W 811.97 308.03 0.43 -0.39 -0.25 2172 48.52 307.45 126 1860.43 906.48 558.19 N 714.24 W 906.48 308.01 0.49 -0.13 -0.63 2299 48.51 307.48 127 1944.55 1001.62 616.06 N 789.76 W 1001.62 307.96 0.02 -0.01 0.02 2425 48.11 307.33 126 2028.36 1095.71 673.21 N 864.50 W 1095.71 307.91 0.33 -0.32 -0.12 2551 47.74 307.07 126 2112.79 1189.22 729.76 N 938.99 W 1189.23 307.85 0.33 -0.29 -0.21 2678 47.76 306.84 127 2198.18 1283.21 786.27 N 1014.12 W 1283.22 307.79 0.13 0.02 -0.18 2771 47.26 308.12 93 2261.00 1351 .79 828.00 N 1068.54 W 1351.80 307.77 1.15 -0.54 1.38 2898 47.28 308.69 127 2347.18 1445.07 885.95 N 1141.64 W 1445.08 307.81 0.33 0.02 0.45 3024 47.22 308.40 126 2432.70 1537.59 943.61 N 1214.01 W 1537.60 307.86 0.18 -0.05 -0.23 3150 47.10 308.25 126 2518.38 1629.98 1000.90 N 1286.49 W 1629.98 307.88 0.13 -0.10 -0.12 3276 46.94 307.68 126 2604.28 1722.16 1057.61 N 1359.16 W 1722.16 307.89 0.35 -0.13 -0.45 3403 47.21 308.42 127 2690.77 1815.15 1114.92 N 1432.39 W 1815.16 307.90 0.48 0.21 0.58 3529 47.11 308.51 126 2776.44 1907.54 1172.39 N 1504.73 W 1907.54 307.92 0.10 -0.08 0.07 3655 47.01 308.64 126 2862.28 1999.78 1229.91 N 1576.84 W 1999.78 307.95 0.11 -0.08 0.10 3781 47.19 308.79 126 2948.05 2092.07 1287.64 N 1648.86 W 2092.07 307.99 0.17 0.14 0.12 3805 46.99 308.72 24 2964.39 2109.65 1298.64 N 1662.57 W 2109.65 307.99 0.86 -0.83 -0.29 3889 47.69 308.19 84 3021.31 2171.42 1337.06 N 1710.94 W 2171.42 308.01 0.95 0.83 -0.63 3982 46.31 307.66 93 3084.74 2239.43 1378.86 N 1764.59 W 2239.43 308.00 1.54 -1.48 -0.57 4077 42.99 307.14 95 3152.31 2306.18 1419.42 N 1817.62 W 2306.18 307.99 3.52 -3.49 -0.55 4171 41.64 303.60 94 3221.83 2369.37 1456.05 N 1869.18 W 2369.38 307.92 2.91 -1.44 -3.77 4266 38.76 305.89 95 3294.39 2430.58 1490.96 N 1919.58 W 2430.59 307.84 3.41 -3.03 2.41 4361 36.35 306.98 95 3369.70 2488.45 1525.34 N 1966.17 W 2488.47 307.80 2.63 -2.54 1.15 4408 35.52 306.98 47 3407.75 2516.03 1541 .93 N 1988.20 W 2516.05 307.79 1.77 -1.77 0.00 4488 35.28 307.50 80 3472.96 2562.37 1569.97 N 2025.10 W 2562.39 307.78 0.48 -0.30 0.65 4550 35.48 307.26 62 3523.51 2598.26 1591.76 N 2053.62 W 2598.28 307.78 0.39 0.32 -0.39 4645 36.05 307.26 95 3600.60 2653.78 1625.38 N 2097.81 W 2653.80 307.77 0.60 0.60 0.00 . ~ El")()(.:H . 24 . UNOCALe Happy Valley #10 4740 35.70 306.97 95 3677.57 2709.45 1658.97 N 2142.21 W 2709.47 307.76 0.41 -0.37 -0.31 4834 35.50 306.57 94 3754.01 2764.15 1691.73 N 2186.04 W 2764.18 307.74 0.33 -0.21 -0.43 4929 35.38 307.72 95 3831.40 2819.23 1724.99 N 2229.95 W 2819.26 307.72 0.71 -0.13 1.21 5023 35.08 306.33 94 3908.19 2873.45 1757.64 N 2273.23 W 2873.48 307.71 0.91 -0.32 -1.48 5118 34.97 306.54 95 3985.98 2927.95 1790.02 N 2317.10 W 2927.99 307.69 0.17 -0.12 0.22 5213 33.61 309.78 95 4064.48 2981 .45 1823.06 N 2359.19 W 2981.49 307.70 2.40 -1.43 3.41 5308 33.40 308.53 95 4143.69 3033.88 1856.17 N 2399.85 W 3033.92 307.72 0.76 -0.22 -1.32 5402 33.04 309.47 94 4222.33 3085.37 1888.58 N 2439.87 W 3085.40 307.74 0.67 -0.38 1.00 5497 32.70 308.04 95 4302.12 3136.92 1920.86 N 2480.07 W 3136.95 307.76 0.89 -0.36 -1.51 5592 32.79 309.05 95 4382.03 3188.30 1952.88 N 2520.26 W 3188.33 307.77 0.58 0.09 1.06 5686 32.65 309.55 94 4461.11 3239.10 1985.06 N 2559.58 W 3239.12 307.80 0.32 -0.15 0.53 5781 32.16 307.51 95 4541.32 3290.00 2016.77 N 2599.40 W 3290.02 307.81 1.26 -0.52 -2.15 5876 32.03 309.19 95 4621.80 3340.47 2048.09 N 2638.98 W 3340.49 307.81 0.95 -0.14 1.77 5971 31 .46 308.61 95 4702.59 3390.45 2079.47 N 2677.88 W 3390.46 307.83 0.68 -0.60 -0.61 6065 31.10 306.94 94 4782.93 3439.25 2109.37 N 2716.45 W 3439.27 307.83 1.00 -0.38 -1.78 6160 30.74 306.74 95 4864.43 3488.05 2138.64 N 2755.52 W 3488.07 307.82 0.39 -0.38 -0.21 6255 29.79 307.05 95 4946.48 3535.93 2167.38 N 2793.81 W 3535.95 307.80 1.01 -1.00 0.33 6349 29.58 307.61 94 5028.14 3582.4 7 2195.61 N 2830.82 W 3582.50 307.80 0.37 -0.22 0.60 6444 29.26 307.60 95 5110.89 3629.14 2224.09 N 2867.79 W 3629.16 307.80 0.34 -0.34 -0.01 6539 28.54 306.84 95 5194.06 3675.04 2251.86 N 2904.35 W 3675.07 307.79 0.85 -0.76 -0.80 6634 28.06 306.60 95 5277.71 3720.07 2278.79 N 2940.45 W 3720.10 307.77 0.52 -0.51 -0.25 6760 27.02 306.08 126 5389.43 3778.30 2313.32 N 2987.38 W 3778.34 307.75 0.85 -0.83 -0.41 6886 26.21 306.56 126 5502.07 3834.72 2346.75 N 3032.86 W 3834.77 307.73 0.67 -0.64 0.38 7013 25.26 307.99 127 5616.48 3889.86 2380.13 N 3076.74 W 3889.91 307.73 0.89 -0.75 1.13 7139 24.53 306.99 126 5730.77 3942.90 2412.42 N 3118.82 W 3942.94 307.72 0.67 -0.58 -0.79 7266 23.57 306.28 127 5846.74 3994.64 2443.30 N 3160.35 W 3994.69 307.71 0.79 -0.76 -0.56 7392 22.66 307.75 126 5962.63 4044.09 2473.07 N 3199.85 W 4044.15 307.70 0.86 -0.72 1.17 7518 22.15 308.56 126 6079.12 4092.11 2502.74 N 3237.61 W 4092.17 307.70 0.47 -0.40 0.64 7645 21.09 307.37 127 6197.18 4138.90 2531.53 N 3274.50 W 4138.96 307. 71 0.90 -0.83 -0.94 7771 20.17 307.78 126 6315.10 4183.30 2558.60 N 3309.68 W 4183.35 307.71 0.74 -0.73 0.33 7865 20.04 308.98 94 6403.37 4215.61 2578.66 N 3335.01 W 4215.66 307.71 0.46 -0.14 1.28 . [~ ET)()(.:H . 25 . UNOCALe Happy Valley #10 7960 19.53 308.29 95 6492.76 4247.76 2598.74 N 3360.13 W 4247.81 307.72 0.59 -0.54 -0.73 8086 18.79 308.50 126 6611.78 4289.11 2624.42 N 3392.54 W 4289.16 307.73 0.59 -0.59 0.17 8212 18.01 309.71 126 6731.34 4328.87 2649.50 N 3423.41 W 4328.92 307.74 0.69 -0.62 0.96 8362 17.42 310.48 150 6874.23 4374.49 2678.89 N 3458.32 W 4374.52 307.76 0.42 -0.39 0.51 8420 17.42 310.48 58 6929.57 4391.83 2690.16 N 3471.53 W 4391.87 307.77 0.00 0.00 0.00 :~ . ~ET)()(_=H . 26 . UNOCALe Happy Valley #10 DAILY MUD PROPERTIES Date FI Depth Den FV PV YP Gels API Cake Solids NAP/H20 Sand PH CI Ca Temp FiI 9/26104 58 56' 9.3 53 23 17 3/510 4.0 1/0 5.2 3/89.5 0.10 8.9 29000 200 9/27/04 80 955' 9.3 65 23 24 10/26/37 4.8 1/0 5.3 2/90.5 0.25 8.5 27500 160 9/28/04 70 955' 9.1 57 19 17 6/18/22 6.0 1/0 3.6 1/93.0 0.10 8.0 29000 120 9/29/04 82 1592' 9.1 57 20 23 8/22/34 5.8 1/0 3.7 2/92.0 0.10 8.5 29000 220 9/30104 84 2793' 9.1 50 15 23 10/22/26 7.4 1/0 3.5 2/92.0 0.10 9.2 31000 180 10/1/04 74 2793' 9.0 54 17 24 9/26/30 6.6 1/0 3.1 3/91.5 0.10 9.1 30000 160 1 0/2/04 70 2823' 9.0 57 18 25 10/28/32 6.2 1/0 3.1 3/91.5 0.10 9.1 29500 140 1 0/3/04 84 3860' 9.4 52 19 20 11/28/36 4.8 1/0 5.6 2/90.0 0.25 9.2 30500 140 10/4/04 66 3850' 9.0 55 15 24 10/12/14 6.6 1/0 2.1 0/95.5 0.10 8.4 29000 100 10/5/04 88 4503' 9.0 50 14 21 7/8/9 5.8 1/0 2.1 0/95.5 0.10 9.2 28500 100 1 016104 74 4545' 9.05 52 19 23 7/8/9 5.1 1/0 2.9 3/91.8 0.10 9.2 29000 100 1 0/7/04 75 4830' 9.05 60 20 27 8/9/10 4.7 1/0 2.7 2.9/92.0 0.10 9.1 30000 150 1 0/8/04 85 6104' 9.05 48 19 19 6/7/8 4.8 1/0 2.8 3.2/91.4 0.10 9.4 31000 150 1 0/9/04 86 7534' 9.25 53 19 25 7/8/1 0 4.1 1/0 3.8 3.3/90.3 0.10 9.4 33000 200 10/10104 81 7859' 9.35 51 21 24 6/7/9 3.9 1/0 4.8 3.8/89.1 0.10 9.5 30000 150 10/11/04 84 8221' 9.30 53 17 19 5/9/14 3.8 1/0 4.5 3.6/89.6 0.10 9.2 29500 140 10/12/04 73 8420' 9.35 51 16 18 5/7/10 3.6 1/0 4.8 3.5/89.4 0.00 9.1 29000 160 . ~ EP~(=H 27 . UNOCALe Happy Valley #10 BIT RECORD Bit Grading I 0 D L B G 0 R N U U 0 E A T E N T L C A U H A E E L A R G E S R R T I E R 0 C I N N R R H 0 G C 0 0 A N S H P W W R A U S S R L L E D Bit Size Make Type SIN Jets Depth Depth Ftg. Hrs. Ave Ave Ave Ave No. In Out FtlHr WOB RPM PSI 1 12.25 HC MX-C1 6026447 3X16 56' 995' 939' 3.8 275 10.8 29 1511 1 1 W A E I N TO 1X12 T 0 2 8.5 HC MX-C1 6018848 3X16 995' 2823' 1828' 12.2 180 11.8 80 1489 2 3 W A E I B BH 1X12 T T A 3RR1 8.5 SEC FS2653 10414701 6X12 2823' 3860' 1037' 6.9 150 2.9 104 2137 0 6 C S X I W TO T T 4 6.125 HC HCM 406 7102177 3X16 3860' 4503' 643' 6.9 93 2.7 63 1411 0 1 W S X I N CP Rebuilt T 0 5 6.125 HC ACX-425 7300788 TFA 4503' 4510' 7' .6 11.7 4.1 62 1285 Core #1 .66 - - - - - - - - 4RR1 6.125 HC HCM 406 7102177 3X16 4510' 4545' 35 .3 117 3.1 81 1639 0 1 W S X I N CP Rebuilt T 0 5RR1 6.125 HC ACX-425 7300788 TFA 4545' 4636' 90' 6.7 13 6.5 50 1160 Core #2 .66 - - - - - - - - 4RR2 6.125 HC HCM 406 7102177 3X16 4636' 7828' 3191' 30.0 106 5.4 78 2203 0 1 W S X I E CP Rebuilt T R 5RR2 6.125 HC ACX-425 7300788 TFA 7828' 7859' 31' 4.6 6.7 4.3 58 1685 Core #3 .66 - - - - - - - - I 4RR3 6.125 HC HCM 406 7102177 3X16 7859' 8420' 561' 7.0 80 4.0 70 2485 0 1 W S X I E TO Rebuilt T R . [~ EPO(_~H . 28 . . UNOCAL AFE #163066 DAILY WELLSITE REPORT g EPOCH Happy Valley #10 REPORT FOR DON FOWLER DATE Sep 27. 2004 DEPTH 955.00000 PRESENT OPERATION PREP TO RUN 9 5/8" CASING TIME 11:59 PM YESTERDAY 53.00 24 HOUR FOOTAGE 902 . CASING INFORMATION 133/8" @ 56' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 955' 20.57 307.72 938.40 SURVEY DATA 890' 19.17 307.72 877.27 859' 18.49 308.66 847.93 796' 16.96 310.40 787.92 733 15.75 310.46 727.47 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 1 12.25" MX-C1 6026447 3X16,1X12 53 955 902 3.8 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 506.0 @ 183.00 36.1 @ 57.00 275.7 214.28500 FTIHR SURFACE TORQUE 5529 @ 834.00 80 @ 792.00 1929.2 2807.90000 AMPS WEIGHT ON BIT 18 @ 785.00 SLIDE @ 171.00 10.8 7.59500 KLBS ROTARY RPM 48 @ 603.00 SLIDE @ 311.00 28.9 44.56000 RPM PUMP PRESSURE 1822 @ 922.00 80 @ 53.00 1511.4 1637.89800 PSI DRILLING MUD REPORT DEPTH 955' MW 9.3 VIS 65 PV 23 YP 24 FL 4.8 Gels 10/26/37 CL- 27500 FC 1/0 SOL 5.3 SD 0.25 OIL 2.0 MBL pH 8.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 823.00 o @ 160.00 2.4 TRIP GAS 0 CUTTING GAS 0 @ 955.00000 o @ 955.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 2293 @ 823.00 38 @ 77.00 475.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 955.00000 o @ 955.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 955.00000 o @ 955.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 955.00000 o @ 955.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 955.00000 o @ 955.00000 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAY, SILT, SAND, COAL PRESENT LITHOLOGY 955' = 10% CONGLOMERATE SAND, 20% SAND, 20% SILT, 50% CLAY DAILY ACTIVITY FINISH RIGGING UP, SPUD WELL AND DRILL TO CASING POINT (955'), CIRCULATED THE WELL AND SUMMARY DROPPED A CARBIDE, LAG DETERMINED A VERY CLOSE TO GAUGED HOLE, PULL OUT OF THE HOLE AND LAY DOWN THE SMART IRON, RIG UP TO RUN 9 5/8" CASING. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 DML + $325 RW = $2790 REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163066 DAIL Y WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR DOUG NEIHAUS DATE Sep 28, 2004 DEPTH 955.00000 PRESENT OPERATION TEST BOPE TIME 11 :59 PM YESTERDAY 955.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 943' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 955' 20.57 307.72 938.40 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 955' MW 9.1 VIS 57 PV 19 YP 17 FL 6.0 Gels 6/18/22 CL- 29000 FC 1/0 SOL 3.6 SD 0.10 OIL 1 MBL pH 8.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENTBACKGROUNDMVG PENTANE (C-5) @ @ HYDROCARBON SHOWS NO DRILLING MUD CIRCULATED THE LAST 24 HOURS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY FINISHED RUNNING CASING AND CEMENTED AND BUMPED THE PLUG, HELD 3500 PSI FOR 30 SUMMARY MINS., NIPPLE UP AND TEST BOPE. . . EPOCH PERSONNEL ON 4 BOARD REPORT BY LEES F. BROWNE JR. DAILY $2790 (2465 DML + $325 RIG WATCH) TOTAL 9/28/04 = COST $9960.38 . UNOCAL AFE #163066 DAILY WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR DOUG NEIHAUS DATE Oct 01, 2004 DEPTH 2792.00 PRESENT OPERATION TRIP IN TO FISH BHA TIME 11 :59 PM YESTERDAY 2792.00 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 943' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2792' 2275.2' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 MX-C1 6018848 3X16,1X12 955 11.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTIHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2792' MW 9.0 VIS 54 PV 17 YP 24 FL 6.6 Gels 9/26/30 CL- 30000 FC 1/0 SOL 3.1 SD 0.10 OIL 3 MBL pH 9.1 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS DP IN GROUND = 0, CONNECTION TIME: 010 AVE. SURVEY TIME: OIOAVE. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2 CIRC @ 2792 .5 @2792 1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUNDIAVG 1 CIRC THROUGH PITS PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LlTHOLOGYIREMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CONTINUED TO WORK STUCK PIPE, PUMPED ONE BARREL EVERY 2.5 HOURS, RIGGED UP WIRE LINERS DAILY AND RAN FREE POINT, PICKED UP STRING SHOT AND SHOT, PIPE DID NOT COME LOOSE, RIGGED UP AND SHOT A SECOND STRING SHOT AT 2685', = CAME LOOSE, CIRCULATED OUT OIL BASE MUD SPOTTING ACTIVITY FLUID AND DUMPED, PULL OUTOF THE HOLE AND LAY DOWN CROSS OVER AND TWO FLEX COLLARS, SUMMARY PICK UP FISHING ASSEMBLY, MIXED SACKED FISHING TOOL SPOTTING FLUID, TRIP INTO THE HOLE TO THE SHOE AND BEGIN TO CUT AND SLIP DRILL LINE. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY LEES F. BROWNE JR. . . . UNOCAL AFE #163066 DAILY WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR DOUG NEIHAUS DATE Oct 02, 2004 DEPTH 2823.00 PRESENT OPERATION TRIP IN TO DRILL TIME 11 :59 PM YESTERDAY 2793.00 24 HOUR FOOTAGE 30 CASING INFORMATION 9.625" @ 943' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 2823' 2295.9' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 MX-C1 6018848 3X16,1X12 955 12.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 206.0 @ 2802.00 84.7 @ 2812.00 155.7 87.07304 FT/HR SURFACE TORQUE 5196 @ 2822.00 4845 @ 2819.00 5140.6 5079.94971 AMPS WEIGHT ON BIT 15 @ 2822.00 11 @ 2814.00 14.1 12.25022 KLBS ROTARY RPM 95 @ 2813.00 93 @ 2822.00 98.0 94.78097 RPM PUMP PRESSURE 1999 @ 2805.00 1890 @ 2814.00 2004.7 1903.17139 PSI DRILLING MUD REPORT DEPTH 2823' MW 9.0 VIS 57 PV 18 YP 25 FL 6.2 Gels 10128/32 CL- 29500 FC 1/0 SOL 3.1 SO 0.10 OIL 3 MBL pH 9.1 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS DP IN GROUND := 30'/5.0 MINS := 6.0 GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 4 @ 2804.00 0 @ 2821.00 2.4 TRIP GAS 8 @ 2792' CUTTING GAS 0 @ 2823.00 o @ 2823.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 763 @ 2804.00 85 @ 2823.00 442.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 2823.00 o @ 2823.00 0.0 AVG 0 PROPANE (C-3) 0 @ 2823.00 o @ 2823.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2823.00 o @ 2823.00 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 2823.00 o @ 2823.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TRIP IN THE HOLE WITH CUT LIP FISHING ASSEMBLY. TAGGED THE FISH AT 2686' AND SCREWED INTO IT. DAILY WORKED FISH DOWN HITTING THE BUMPER SUB, FISH CAME FREE, TAGGED BOTTOM AT 2792' AND ACTIVITY DRILLED TO 2823', NO MWD PLUSE, CIRCULATED BOTTOMS UP (8 UNITS OF TRIP GAS), AND PULLED OUT SUMMARY OF THE HOLE. WASH AND REAM TO THE SHOE, LAY DOWN FISHING ASSEMBLY AND REPAIR THE TOP DRIVE, PICK UP BHA AND TRIP IN THE HOLE TO DRILL. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY LEES F. BROWNE JR. · UNOCAL DAIL Y WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR Larry McAllister DATE Oct 03,2004 DEPTH 3860.00 PRESENT OPERATION Trip out with BHA at casing pt. TIME 11 :59 pm YESTERDAY 2823.00 24 HOUR FOOTAGE 1037 CASING INFORMATION 9.625" @ 943' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3805' 46.99 308.72 3001.91 ' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2rr 8.5 MX-C1 6018848 3X16,12 2823' 3860' 1037' 6.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 286.7 @ 3457.00 37.8 @ 3858.00 166.4 50.00000 FTIHR SURFACE TORQUE 6651 @ 3857.00 1720 @ 3771.00 4642.7 5170.48535 AMPS WEIGHT ON BIT 12 @ 2824.00 0 @ 3583.00 2.8 1.02365 KLBS ROTARY RPM 110 @ 2833.00 28 @ 3771.00 103.6 94.09447 RPM PUMP PRESSURE 2406 @ 3857.00 1507 @ 3771.00 2137.2 2186.77490 PSI DRILLING MUD REPORT DEPTH 3860 MW 9.4 VIS 52 PV 19 YP 20 FL 4.8 Gels 11/28/36 CL- 30500 FC 1/0 SOL 5.6 SD 0.25 OIL 0 MBL 7.5 pH 9.20 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS DP IN GROUND = 1037'110.9 HRS = 95 FTIHR GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 43 @ 2834.00 0 @ 2875.00 11.2 TRIP GAS CUTTING GAS 0 @ 3860.00 0 @ 3860.00 0.0 WIPER GAS 35u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8543 @ 2834.00 42 @ 2875.00 2149.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 12 @ 3318.00 0 @ 3301.00 0.1 AVG 0 PROPANE (C-3) 0 @ 3860.00 0 @ 3860.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3860.00 0 @ 3860.00 0.0 CURRENT BACKGROUND/A VG 4/11 PENTANE (C-5) 0 @ 3860.00 0 @ 3860.00 0.0 HYDROCARBON SHOWS NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND 30%, COAL 10%, CLAYSTONE 30%, SILTSTONE 30% PRESENT LITHOLOGY SAND 40%, CLAYSTONE 20%, SILTSTONE 40% DAILY ACTIVITY Finish trìpping in hole and drill from 2823' to casing point at 3860'. Circulate bottoms up, circulate LCM sweep, and SUMMARY drop and circulate out carbide. Short trip to 2600', rotating and circulating through tight spots. Trip in hole and condition mud, 35 units of trip gas. Pull out of hole and monitor well at shoe. Pulling BHA at midnight. · · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY Brian O'Fallon · UNOCAL DAIL Y WELLSITE REPORT g EPOCH Happy Valley #10 REPORT FOR DATE Oct 04, 2004 DEPTH 3860.00 PRESENT OPERATION PIU singles to bottom TIME 11:59 PM YESTERDAY 3860.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3805' 46.99 308.72 3001.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 4 61/8" HC HCM406 7102177 3X16 3860' 0 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FTIHR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 3850' MW 9.0 VIS 55 PV 15 YP 24 FL 6.6 Gels 10/12/14 CL- 29000 FC 1/0 SOL 2.1 SD 0.10 OIL 0 MBL 0.0 pH 8.4 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS DP IN GROUND = 0 GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 32 @ 3 @ 6 TRIP GAS 7u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) NA @ NA @ NA CONNECTION GAS HIGH NA ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C-3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUNDIAVG 1/6 PENTANE (C-5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY SAND 40%, CLAYSTONE 20%, SILTSTONE 40% DAIL Y ACTIVITY Finished pulling out of hole with BHA and laid down string. Rigged up and ran 7" casing. Rigged up and cemented SUMMARY casing. Pressure tested to 3500 psi, and nippled up and tested BOPs. Picked up new BHA with 6 1/8" bit, and picked up and ran in hole with DP, while cleaning pits and mixing new mud. · · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY $2790 · UNOCAL DAIL Y WELLSITE REPORT g EPOCH Happy Valley #10 REPORT FOR Brown I Niehaus DATE Oct 05, 2004 DEPTH 4503.00 PRESENT OPERATION Trip out for core barrel TIME 11 :59 PM YESTERDAY 3860.00 24 HOUR FOOTAGE 643 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4361' 36.35 306.98 3369.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 4 61/8" HC HCM406 7102177 3x16 3860 4503 643' 6.9 CORE PT. DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 302.3 @ 4436.00 8.9 @ 4140.00 124.7 125.59267 FT/HR SURFACE TORQUE 5790 @ 4365.00 139 @ 4001.00 3967.5 4955.27051 AMPS WEIGHT ON BIT 12 @ 4260.00 0 @ 4166.00 2.7 4.80873 KLBS ROTARY RPM 90 @ 4498.00 0 @ 3993.00 62.7 90.11795 RPM PUMP PRESSURE 1754 @ 4225.00 753 @ 3976.00 1410.3 1664.12390 PSI DRILLING MUD REPORT DEPTH 4503 MW 9.00 VIS 50 PV 14 YP 21 FL 5.5 Gels 7/8/9 CL- 28500 FC 1/0 SOL 2.1 SD 0.10 OIL 0 MBL 1.0 pH 9.20 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND 643'/15.0 HOURS = 42.9'/HR CONNECTION = 52 MIN, SURVEY = 97 MIN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 119 @ 4203.00 1 @ 3861.00 23.6 TRIP GAS 3u CUTTING GAS 0 @ 4503.00 0 @ 4503.00 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 21968 @ 3934.00 175 @ 3861.00 4486.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 24 @ 3934.00 0 @ 3882.00 2.4 AVG 0 PROPANE (C-3) 0 @ 4503.00 0 @ 4503.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 4503.00 0 @ 4503.00 0.0 CURRENT BACKGROUNDIAVG NA/24 PENTANE (C-5) 0 @ 4503.00 0 @ 4503.00 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL 10%, SAND 30%, CLAYSTONE 50%, SILTSTONE 10% PRESENT LITHOLOGY COAL 40%, SAND 30%, CLAYSTONE 20%, SILTSTONE 10% DAILY Tripped in hole to 3752' and tested casing to 3500 psi for 30 minutes. Performed choke drill and drilled out cement ACTIVITY and shoe and 20' of new formation down to 3880'. Displaced hole with new mud and performed LOT to 13.7 ppg SUMMARY emw. Drilled ahead, rotating and sliding, to core point at 4503'. Circulated hole clean and pulled out of hole for core barrel. · · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY Brian O'Fallon . . . UNOCAL DAIL Y WELLSITE REPORT g EPOCH Happy Valley #10 REPORT FOR Brown/Niehaus DATE Oct 07,2004 DEPTH 4984.00 PRESENT OPERATION Drilling TIME 11 :59 PM YESTERDAY 4546.00 24 HOUR FOOTAGE 438 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4834' 35.50 306.57 3754.01' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 7(5rr) 61/8" HC HCM406 7102177 3X16 4546 4636 90 6.7 90' CORE 8( 4rr) 61/8" HC HC ACX425 7300788 6X12 4636 248 3.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 208.4 @ 4805.00 1.9 @ 4573.00 98.5 149.56p91 FT/HR SURFACE TORQUE 5280 @ 4981.00 2203 @ 4701.00 4847.6 5078.50732 AMPS WEIGHT ON BIT 9 @ 4633.00 0 @ 4546.00 5.3 4.26562 KLBS ROTARY RPM 82 @ 4853.00 33 @ 4546.00 73.1 78.46517 RPM PUMP PRESSURE 2100 @ 4961.00 782 @ 4546.00 1777.6 2006.95654 PSI DRILLING MUD REPORT DEPTH 4830' MW 9.05 VIS 60 PV 20 YP 27 FL 4.7 Gels 8/9/1 0 CL- 30000 FC 1/0 SOL 2.7 SO 0.10 OIL 2.9 MBL 1.0 pH 9.10 Ca+ 150 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND: BIT#7(CORE) 7 hrs 25 min; BIT#8(DRILL) 5 hrs 55 min; connection 28 min, survey 19 min. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 169 @ 4946.00 3 @ 4631.00 35.6 TRIP GAS 32u@4546',22u@4636' CUTTING GAS 0 @ 4984.00 0 @ 4984.00 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 29621 @ 4946.00 599 @ 4631.00 6330.2 CONNECTION GAS HIGH 0 ETHANE (C-2) 24 @ 4947.00 0 @ 4606.00 3.5 AVG 0 PROPANE (C-3) 2 @ 4967.00 0 @ 4946.00 0.2 CURRENT 0 BUTANE (C-4) 0 @ 4984.00 0 @ 4984.00 0.0 CURRENT BACKGROUND/AVG 28/36 PENTANE (C-5) 0 @ 4984.00 0 @ 4984.00 0.0 HYDROCARBON SHOWS 4540-4555':SAND,79u INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 10% COAL, 20% SAND, 70% CLAYSTONE PRESENT LITHOLOGY 20% COAL, 10% SAND, 70% CLAYSTONE DAILY ACTIVITY Run in hole with core barrel assembly and core from 4546' to 4636'. Circulate bottoms up and pull out of hole SUMMARY with core barrel. Pick up drilling assembly and run in hole. Drill from 4636' to 4984' EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY Brian O'Fallon · UNOCAL DAIL Y WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR Brown I Niehaus DATE Oct 05, 2004 DEPTH 4503.00 PRESENT OPERATION Trip out for core barrel TIME 11 :59 PM YESTERDAY 3860.00 24 HOUR FOOTAGE 643 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4361' 36.35 306.98 3369.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 4 6 1/8" HC HCM406 7102177 3x16 3860 4503 643' 6.9 CORE PT. DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 302.3 @ 4436.00 8.9 @ 4140.00 124.7 125.59267 FTIHR SURFACE TORQUE 5790 @ 4365.00 139 @ 4001.00 3967.5 4955.27051 AMPS WEIGHT ON BIT 12 @ 4260.00 0 @ 4166.00 2.7 4.80873 KLBS ROTARY RPM 90 @ 4498.00 0 @ 3993.00 62.7 90.11795 RPM PUMP PRESSURE 1754 @ 4225.00 753 @ 3976.00 1410.3 1664.12390 PSI DRILLING MUD REPORT DEPTH 4503 MW 9.00 VIS 50 PV 14 YP 21 FL 5.5 Gels 7/8/9 CL- 28500 FC 1/0 SOL 2.1 SD 0.10 OIL 0 MBL 1.0 pH 9.20 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND 643'/15.0 HOURS = 42.9'/HR CONNECTION = 52 MIN, SURVEY = 97 MIN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 119 @ 4203.00 1 @ 3861.00 23.6 TRIP GAS 3u CUTTING GAS 0 @ 4503.00 0 @ 4503.00 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 21968 @ 3934.00 175 @ 3861.00 4486.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 24 @ 3934.00 0 @ 3882.00 2.4 AVG 0 PROPANE (C-3) 0 @ 4503.00 0 @ 4503.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 4503.00 0 @ 4503.00 0.0 CURRENT BACKGROUND/AVG NA/24 PENTANE (C-5) 0 @ 4503.00 0 @ 4503.00 0.0 HYDROCARBON SHOWS None INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL 10%, SAND 30%, CLAYSTONE 50%, SILTSTONE 10% PRESENT LITHOLOGY COAL 40%, SAND 30%, CLAYSTONE 20%, SILTSTONE 10% DAILY Tripped in hole to 3752' and tested casing to 3500 psi for 30 minutes. Performed choke drill and drilled out cement ACTIVITY and shoe and 20' of new formation down to 3880'. Displaced hole with new mud and performed LOT to 13.7 ppg SUMMARY emw. Drilled ahead, rotating and sliding, to core point at 4503'. Circulated hole clean and pulled out of hole for core barrel. · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 · REPORT BY Brian O'Fallon . UNOCAL DAIL Y WELLSITE REPORT g EPOCH Happy Valley #10 REPORT FOR BrownlNiehaus DATE Oct 06, 2004 DEPTH 4545.00 PRESENT OPERATION Run in with core barrel TIME 11 :59 PM YESTERDAY 4503.00 24 HOUR FOOTAGE 42 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4361' 36.35 306.98 3369.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 6( 4rr) 6 1/8" HC HCM406 7102177 3X16 4510 4545' 35 0.3 core point 5 6 1/8" HC ACX425 7300788 6X12 4503' 4510' 7' 0.9 barrel jammed DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 384.4 @ 4518.00 5.0 @ 4505.00 175.9 246.97266 FTIHR SURFACE TORQUE 5763 @ 4518.00 3900 @ 4508.00 5188.7 5484.88965 AMPS WEIGHT ON BIT 6 @ 4510.00 1 @ 4545.00 3.1 1.00000 KLBS ROTARY RPM 85 @ 4520.00 40 @ 4504.00 76.1 79.98262 RPM PUMP PRESSURE 1920 @ 4518.00 969 @ 4510.00 1554.3 1670.02673 PSI DRILLING MUD REPORT DEPTH 4545' MW 9.05 VIS 52 PV 19 YP 23 FL 5.1 Gels 7/8/9 CL- 29000 FC 1/0 SOL 2.9 SD 0.10 OIL 0 MBL 1.0 pH 9.20 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND: BIT#5(CORE) 1 hr 50 mins (8 min connection), BIT#6(DRILL) 3 hrs 50 min GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 79 @ 4544.00 9 @ 4511.00 35.5 TRIP GAS 45u@4503, 5@4510' CUTTING GAS 0 @ 4545.00 0 @ 4545.00 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) 15535 @ 4544.00 1764 @ 4511.00 6982.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 8 @ 4545.00 0 @ 4524.00 2.3 AVG 0 PROPANE (C-3) 0 @ 4545.00 0 @ 4545.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 4545.00 0 @ 4545.00 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 4545.00 0 @ 4545.00 0.0 HYDROCARBON SHOWS NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 10% SAND, 10% COAL, 80% CLAYSTONE PRESENT LITHOLOGY 50% SAND, 50% CLAYSTONE DAILY ACTIVITY Trip in hole and core from 4503' to 4510', core barrel jammed, and pull out of hole. Recovered 3' of core and picked SUMMARY up drilling assembly. Run in hole and drilled at 5' intervals from 4510' to 4545', circulating out after each interval looking for sand. Pulled out of hole to pick up core barrel, and begin running in hole with core barrel . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 . REPORT BY Brian O'Fallon · UNOCAL DAIL Y WELLSITE REPORT ~ EPOCH Happy Valley #10 REPORT FOR Brown/Niehaus DATE Oct 08, 2004 DEPTH 6109.00 PRESENT OPERATION Drilling TIME 11 :59 PM YESTERDAY 4984.00 24 HOUR FOOTAGE 1125 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4834' 35.50 306.57 3754.01 ' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 8(rr4) 61/8" HC HCM406 7102177 3X16 4636 1473 13.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 288.0 @ 5083.00 19.4 @ 6106.00 131.1 55.34363 FTIHR SURFACE TORQUE 7567 @ 6085.00 169 @ 5196.00 5600.7 6327.70801 AMPS WEIGHT ON BIT 23 @ 5196.00 0 @ 6030.00 6.3 3.15536 KLBS ROTARY RPM 87 @ 5047.00 0 @ 5194.00 78.0 77.44272 RPM PUMP PRESSURE 2650 @ 5483.00 1181 @ 6105.00 2201.0 1776.86584 PSI DRILLING MUD REPORT DEPTH 6104' MW 9.05 VIS 48 PV 19 YP 19 FL 4.8 Gels 6/7/8 CL- 31000 FC 1/0 SOL 2.8 SD 0.10 OIL 3.3 MBL 1.0 pH 9.40 Ca+ 150 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND:19.2 HRS; CONN 73 MIN., SURVEY 44 MIN. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1313 @ 5493.00 6 @ 6105.00 207.8 TRIP GAS CUTTING GAS 0 @ 6109.00 0 @ 6109.00 0.0 WIPER GAS 293u@6104' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 221358 @ 5493.00 1202 @ 6105.00 36748.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 220 @ 5494.00 0 @ 6105.00 37.6 AVG 0 PROPANE (C-3) 48 @ 5492.00 0 @ 5005.00 9.7 CURRENT 0 BUTANE (C-4) 16 @ 5492.00 0 @ 5397.00 1.9 CURRENT BACKGROUND/AVG 208/120 PENTANE (C-5) 0 @ 6109.00 0 @ 6109.00 0.0 HYDROCARBON SHOWS 5405-5440': SAND, 571u; 5458-5550': SAND, 1313u INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION LITHOLOGY 20% Sand, 10% Coal, 70% Claystone PRESENT LITHOLOGY 90% Claystone, 10% Sand DAILY Drilled from 4984' to 5931', and circulated bottoms up to search for core point. Drilled ahead to 6030' and circulated ACTIVITY bottoms up, and drilled and circulated bottoms up 7 more intervals down to 6105' searching for core point. SUMMARY Determined not to core, and performed wiper trip, reaming through tight spots on trip out. Drilled ahead from 6105' to 6109'. · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 · REPORT BY Brian O'Fallon . . UNOCAL DAIL Y WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR Doug Niehaus/Jim Brown DATE Oct 10, 2004 DEPTH 7859.00 PRESENT OPERATION Coring TIME 11:59 PM YESTERDAY 7618.00 24 HOUR FOOTAGE 241 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7771' 20.17 307.78 6315.10' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 8(4RR) 61/8" HC HCM406 7102177 3X16 4636 7828 192 30.0 Core Point 9 6118" HC ACX425 7828 7859 31 6.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 177.1 @ 7706.00 1.0 @ 7835.00 93.5 1.15756 FT/HR SURFACE TORQUE 9171 @ 7707.00 3491 @ 7701.00 8445.1 7039.58154 AMPS WEIGHT ON BIT 8 @ 7784.00 0 @ 7832.00 5.6 8.23743 KLBS ROTARY RPM 77 @ 7697.00 27 @ 7701.00 73.7 59.33522 RPM PUMP PRESSURE 2720 @ 7710.00 1119 @ 7828.00 2363.1 1670.65833 PSI DRILLING MUD REPORT DEPTH 7859 MW 9.35 VIS 51 PV 21 YP 24 FL 3.9 Gels 6/7/9 CL- 30000 FC 1/0 SOL 4.8 SO 0.10 OIL 3.8 MBL pH 9.50 Ca+ 150 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND: BIT#8(DRILL) 4.3 HRS, CONN 16 MIN, SURVEY 8 MIN: BIT#9(CORE): 6.3 HRS. . GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 977 @ 7713.00 37 @ 7859.00 279.0 TRIP GAS 715u@7827' CUTTING GAS 0 @ 7859.00 0 @ 7859.00 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 189647 @ 7713.00 5144 @ 7835.00 51615.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 249 @ 7713.00 8 @ 7859.00 55.9 AVG 0 PROPANE (C-3) 54 @ 7712.00 3 @ 7859.00 16.7 CURRENT 0 BUTANE (C-4) 18 @ 7699.00 0 @ 7808.00 2.3 CURRENT BACKGROUND/AVG 371279 PENTANE (C-5) 0 @ 7859.00 0 @ 7859.00 0.0 HYDROCARBON SHOWS GAS SANDS: 7649-7663':873u; 7695-7707':815u; 7837-7851 ':169u INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 20% Coal and Carbonaceous Shale, 30% Sand and Sandstone, 10% Siltstone, 40% Claystone PRESENT LITHOLOGY 60% Sand, 20% Ash Fall Tuff, 20% Claystone DAILY ACTIVITY Drilled ahead from7618' to 7828', circulated bottoms up and decision was made to core. Pulled out of hole and SUMMARY picked up coring assembly. Ran to bottom, pumping through tight spot a 7177', and cored, trip gas 715 units, from 7828' to 7859'. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 . REPORT BY Brian O'Fallon . . . UNOCAL DAILY WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR Brown/Harness DATE Oct 11,2004 DEPTH 8346.00 PRESENT OPERATION Drilling TIME 11 :59 PM YESTERDAY 7859.00 24 HOUR FOOTAGE 487 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8212' 18.01 309.71 6731.34' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5RR2 61/8" HC ACX425 7300788 TFA 0.66 7826 7859 31 6.3 barrel jam 4RR3 61/8" HC HCM406 7102177 3X16 7859 487 5.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRA TrON 198.0 @ 7891.00000 29.6 @ 7952.00 106.9 95.84704 FTIHR SURFACE TORQUE 10754 @ 8235.00 5860 @ 7922.00 8185.4 9212.95313 AMPS WEIGHT ON BIT 8 @ 7859.00 0 @ 8207.00 3.9 4.84336 KLBS ROTARY RPM 80 @ 8161.00 48 @ 7922.00 68.9 77.44009 RPM PUMP PRESSURE 2870 @ 8341.00 1670 @ 7859.00 2435.9 2855.94312 PSI DRILLING MUD REPORT DEPTH 8221' MW 9.30 VIS 53 PV 17 YP 19 FL 3.8 Gels 5/9/14 CL- 29500 FC 1/0 SOL 4.5 SD 0.10 OIL 3.6 MBL 0.0 pH 9.20 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND 8.3 HRS: BIT#5RR2(CORE) 0.3 HRS; BIT#4RR3(DRILL) 8.0 HRS, CONN 43 MIN, SURVEY 22 MIN GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1562 @ 8220.00 37 @ 7859.00 277.8 TRIP GAS 265u@7859' CUTTING GAS 0 @ 8346.00 0 @ 8346.00 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 300000 @ 8221.00 7375 @ 7859.00 49798.5 CONNECTION GAS HIGH 15 ETHANE (C-2) 373 @ 8221.00 8 @ 7859.00 57.9 AVG 7 PROPANE (C-3) 86 @ 8236.00 0 @ 8025.00 17.5 CURRENT 10 BUTANE (C-4) 36 @ 8221.00 0 @ 8288.00 2.6 CURRENT BACKGROUND/AVG 801278 PENTANE (C-5) 0 @ 8346.00 0 @ 8346.00 0.0 HYDROCARBON SHOWS GAS SANDS: 7859-7992':700u; 7930-7937': 554u; 8183'-8240':1562u; 8300-8320':794u INTERVAL LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY 30% SAND, 10% COAL, 10% SILTSTONE, 60% CLAYSTONE PRESENT LITHOLOGY 20% COAL, 20% CARBONACEOUS SHALE, 60% CLAYSTONE DAILY ACTIVITY Finished coring just after midnight and pulled out of hole and laid down core. Pick up drilling assembly and ran SUMMARY in hole to shoe, cut drilling line. Ran in hole to bottom, and drilled from 7859' to 7846'. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY Brian O'Fallon . UNOCAL DAIL Y WELLSITE REPORT U EPOCH Happy Valley #10 REPORT FOR Brown/Harness DATE Oct 12, 2004 DEPTH 8420.00 PRESENT OPERATION Testing BOPs TIME 11 :59 am YESTERDAY 8346.00 24 HOUR FOOTAGE 74 CASING INFORMATION 7"@3849' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8362' 17.42 310.48 6874.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 4RR3 61/8" HC HCM 406 7102177 3X16 7859 8346 561' 7.0 Total Depth DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.6 @ 8377.00 25.9 @ 8395.00 70.5 69.23077 FTIHR SURFACE TORQUE 9607 @ 8418.00 7291 @ 8395.00 9294.6 9267.84961 AMPS WEIGHT ON BIT 6 @ 8347.00 0 @ 8396.00 4.7 3.19583 KLBS ROTARY RPM 80 @ 8411.00 47 @ 8395.00 79.2 80.67503 RPM PUMP PRESSURE 2876 @ 8402.00 2405 @ 8395.00 2845.8 2727.95337 PSI DRILLING MUD REPORT DEPTH 8420' MW 9.35 VIS 51 PV 16 YP 18 FL 3.6 Gels 5/7/10 CL- 29000 FC 1/0 SOL 4.8 SD 0.00 OIL 3.5 MBL 3.0 pH 9.10 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS IN THE GROUND: 4.1 HRS, CONN 7 MIN, SURVEY 4 MIN. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 368 @ 8378.00 63 @ 8363.00 117.8 TRIP GAS CUTTING GAS 0 @ 8420.00 0 @ 8420.00 0.0 WIPER GAS 605u@8420' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 68680 @ 8378.00 10678 @ 8363.00 21445.6 CONNECTION GAS HIGH 5 ETHANE (C-2) 67 @ 8378.00 11 @ 8363.00 22.0 AVG 5 PROPANE (C-3) 27 @ 8378.00 4 @ 8363.00 9.6 CURRENT 5 BUTANE (C-4) 0 @ 8420.00 0 @ 8420.00 0.0 CURRENT BACKGROUND/AVG NA/118 PENTANE (C-5) 0 @ 8420.00 0 @ 8420.00 0.0 HYDROCARBON SHOWS NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 10% SANDSTONE, 10% COAL, 10% SILTSTONE, 70% CLAYSTONE AND CARBONACEOUS SHALE PRESENT LITHOLOGY 20% CARBONACEOUS SHALE, 20% SILTSTONE, 60% CLAYSTONE Drill from 8346' to 8420', total depth, and circulate out. Wiper trip 7 stands and circulate on bottom, 605u of wiper gas, DAILY drop carbide pill, 4720 strokes or 29 barrels over guage, and continue circulating and conditioning hole. Trip out of ACTIVITY hole for e-Iog, and lay down BHI tool for download. Rig up and run Schlumberger wireline down to 7863'. Unable to get SUMMARY past 7863', and logged out of hole. Make second run and have trouble getting down through casing, and found damaged strand in wireline cable with tool at 2700'. Pulled out of hole and laid down damaged cable. Rigged up and tested BOPs. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2790 REPORT BY Brian O'Fallon