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Home My WebLink About204-1701. 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: N2 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: 5984; Total Depth measured 8,478 feet 6302; 6865 feet true vertical 6,999 feet N/A feet Effective Depth measured 5,959 feet 3,046 feet true vertical 4,719 feet 2,420 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 3,083' MD 2,444' TVD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr; N/A 3,046' MD 2,420' 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: 7,240psi3,297'2,584' Burst Collapse 5,410psi Production Liner 5,405' Casing Structural 3-1/2"8,476'6,997' 73'Conductor Surface Intermediate 13-3/8" 7" 73' 3,297' measured TVD 10,160psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-170 50-231-20027-00-00 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 A-09 Plugs Junk measured Length measured true vertical Packer 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' 0 00 0 00 0 Scott Warner, Operations Engineer 325-114 Sr Pet Eng: 10,530psi Sr Pet Geo:Sr Res Eng: WINJ WAG 0 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 p k ft t Fra O s 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 By Grace Christianson at 3:27 pm, Apr 02, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.04.02 11:05:48 - 08'00' Noel Nocas (4361) RBDMS JSB 040325 BJM 5/2/25 DSR-4/2/29 Page 1/1 Well Name: DCU HVA-009 Report Printed: 3/19/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50-231-20027-00-00 Field Name:Deep Creek Unit State/Province:ALASKA Permit to Drill (PTD) #:204-170 Sundry #:325-114 Rig Name/No: Jobs Actual Start Date:3/11/2025 End Date: Report Number 1 Report Start Date 3/12/2025 Report End Date 3/13/2025 Last 24hr Summary PJSM and approve PTW, Spot Fox N2 pump, R/u iron and PT 4500psi. Good PT. SITP 700psi, equalized and open well. Online with N2 at 700scfm, pressure broke over at 2770psi. Pumped 85,487scf to push fluid away. SD pump, SITP 2400psi. R/d Fox SDFN. Report Number 2 Report Start Date 3/13/2025 Report End Date 3/14/2025 Last 24hr Summary PJSM/PTW, R/u YJ EL Unit, SITP 2000psi, Pressure test Lubricator 250-2000psi, good test. RIH w/GPT to 6050', no fluid found. RIH w/2.75"OD CIBP and set at 5984'. Tag plug and confirmed set. Bled TP to 1175psi. Bail dumped 25' of cement on plug at 5984'. Perf BEL_50 sand 5,489'-,5,509'. R/d Lubricator, SDFN. Report Number 3 Report Start Date 3/14/2025 Report End Date 3/15/2025 Last 24hr Summary YJ E-Line. PTW and PJSM. Well died after attempting to flow. SITP 23 psi. Attempt fluid level shot w/ echo meter - inconclusive. RU and RIH w 1-11/16" GPT assy. Fluid level @ 5908' (399' below open perfs). Tag @ 5955' WLM. MU and RIH w/ (2) 2" x 10' Guns on switch. WHP 670 psi. Correlate and perforate 10' BEL 46 sands 5308 - 5318'. Monitor 10 mins. No pressure change. Perforate 10' BEL 45 sands 5265 - 5275'. POH. Gun dry. WHP increased 95 psi to 765 psi in 1 hour. Lay down equipment and secure well. Will flow/test overnight. ****Perf gun 2" Geo Razor, 6 spf, 60* Phsg, 6.8 gms**** Report Number 4 Report Start Date 3/15/2025 Report End Date 3/16/2025 Last 24hr Summary YJ E-Line. PJSM and PTW. Well tested @ 125 MSCFD @ 67 psi overnight. Shut-in and backflow to 710 psi. Shoot fluid level w/ echo meter 5875' and 5886'. MU and RIH w/2" 25' perf gun. WHP 893 psi. Correlate and perforate BEL 41 sand 5019' - 5044'. 5/10/15 min WHP reads: 900/904/907 psi. POH. Gun dry. Flow test well @ ~120 MSCFD @ 68 psi. Shoot fluid level @ 5859' and 5901'. MU and RIH w/2" 10' perf gun. WHP 779 psi. Correlate and perforate BEL 33 sand 4336' - 4346'. 5/10/15 min WHP reads: 779/778/778 psi. POH. Gun dry. Shoot fluid level @5650'. Put well on production. Job Complete ***Perf guns: 2" GEO Razor 6 spf, 60* Phsg, 13 gms*** Well Name:Happy Valley #9 Field:Deep Creek Unit SCHEMATIC State:Alaska T-5 (Frac'd) BEL 33-50 BEL 84 BEL 83 BEL 78 BEL-120/135 BEL_92/99 T-7/8/10/17 T-1B Conductor:13Ǫ", 72 ppf, L-80 to 73' Surface Casing: 7", 26 ppf, L-80, BTC-Mod to 3297' (6.276" ID) Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Production Liner: 3½", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' (2.992" ID) Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete Production Tubing: 3½", 9.2 ppf, L-80 IBT-Mod to 3083' Annulus loaded with 3% KCl brine plus corrosion inhibitor Completion Chemical injection sidepocket mandrel at 2495' (Macco SFO1- CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049'' Baker 80-40 seal assembly 3' of 4.00" OD seals Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP @ 5,984' w/25' of cement 3/13/25 TOC 5,959' 3-1/2" CIBP @ 6,302' 10/9/20 3-1/2" CIBP @ 6,865' w/ 47' of cement 9/29/19 API:50-231-20027-00 AOGCC: 204-170 1104’ FSL, 1300’ FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3½" IBT Tree cxn - 3" Bowen cxn Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs. of 20/40 Ottawa Sand in BJ Lightning-2000 gel. PBTD = 6302' TD = 8478' TOC @ 6,818' 09/30/19 Perf Data See page 2 TOC @ 3,300' (CBL on 11/1/04) Updated by DMA 03-19-25 25' of cement on CIBP @ 5984' per ops report. -bjm Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Length Date Status BEL 33 4336' 4346' 3294' 3303' 10 03/15/25 Open BEL 41 5019' 5044' 3843' 3867' 25 03/15/25 Open BEL 45 5265' 5275' 4062' 4073' 10 03/14/25 Open BEL 46 5308' 5318' 4102' 4111' 10 03/14/25 Open BEL 50 5489' 5509' 4267' 4286' 20 03/13/25 Open BEL 78 6009’6015'4741’4746 6 10/10/20 Open BEL 83 6059’ 6070’ 4785’ 4795’11 10/10/20 Open BEL 84 6106’ 6118’ 4827’ 4838’12 10/10/20 Open BEL_92 6321'6336'5019 5032 15 09/30/19 Isolated 10/9/20 BEL_99 6603'6611'5271 5278 8 09/30/19 Isolated 10/9/20 BEL_120 6885'6905'5523 5541 20 03/26/19 closed BEL_120 6902'6912'5538 5547 10 03/26/19 closed BEL_135 7142'7156'5755 5768 14 03/01/19 closed T-1B 7252'7258'5856 5861 6 03/01/19 closed T-5 7448'7469'6036 6056 21 12/17/05 closed T-5 7440'7470'6029 6057 30 11/09/05 closed T-5 7490'7500'6075 6084 10 11/08/04 closed T-7 7680'7700'6251 6270 20 11/08/04 closed T-8 7760'7786'6326 6350 26 11/08/04 closed T-10 7837'7867'6397 6425 30 11/08/04 closed T-17 8218'8237'6753 6771 19 11/05/04 closed Perforation Details Updated by DMA 03-19-25 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): 8,478'N/A Casing Collapse Structural Conductor Surface 5,410psi Intermediate Production Liner 10,530psi 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 Baker ZXP Pkr; N/A 3,046' MD/2,420' TVD; N/A-N/A 6,999'6,302'5,002' Deep Creek HV Beluga/Tyonek Gas 13-3/8" 7" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Happy Valley A-09CO 553.001 Same ~1,415psi 6302; 6865 Length March 10, 2025 8,476'5,405' 3-1/2" 6,997' Perforation Depth MD (ft): 3-1/2" See Attached Schematic 7,240psi 73'73' 3,297' Size 73' 3,297' MD Hilcorp Alaska, LLC Proposed Pools: 9.2# / L-80 TVD Burst 3,083' 2,584' 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 204-170 50-231-20027-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY 10,160psi Tubing Grade: 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 written approval. Authorized Name and Digital Signature with Date: 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 325-114 By Gavin Gluyas at 10:34 am, Feb 28, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.02.28 10:23:54 - 09'00' Noel Nocas (4361) DSR-2/28/25A.Dewhurst 03MAR25 10-404 BJM 3/10/25 Dump bail 25' of cement on top of CIBP at 5984' md before adding perforations. *&: 3/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.03.10 13:16:46 -08'00' RBDMS JSB 031125 Well Prognosis Well: HVA-09 Well Name: HVA-09 API Number: 50-231-20027-00-00 Current Status: SI Gas Well Permit to Drill Number: 204-170 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: 1843 psi @ 4,286’ TVD Based on 0.43 psi/ft (current open perforations are depleted and will be plugged off) Max. Potential Surface Pressure:1415 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.738 psi/ft using 14.2 ppg EMW FIT at the 7” surface casing shoe (9/18/04) Shallowest Allowable Perf TVD: MPSP/(0.738-0.1) = 1415 psi / 0.638= 2217’ TVD Top of Applicable Gas Pool CO 553A:2872’ MD/ 2306’ TVD (Tyonek/Beluga) Well Status: Shut-in Gas producer since 2019. Current SITP is 72 psi Brief Well Summary HVA-9 was drilled in September 2004 and was originally completed in the T-17 sand which IP’d at 550 MCFD. In November 2004 four additional sands were added which increased production to 950 MCFD. In December 2004 the T6 was frac’d with 100,000 lbs. of 20/40 Ottawa sand which increased the rate to 1.6 MMCFD. In March 2019 the T-1B, BEL135 and BEL120 sands were perforated but did not add any rate. The lower portion of the well was plugged back in 2020 and additional Beluga perfs were added, but they were not successful. Happy Valley A-09 is currently SI. The last perforation job unsuccessfully attempted to flow BEL 78-84. The purpose of this sundry/work is to plug back open zones and perforations in the Bel 33 to Bel 50 sands to return well to production. Notes regarding Wellbore Condition -Min ID: 2.867” (tubing drift ID) -Max inclination: All <50 degrees -Last drift: 6284’ MD (tag) on 2/23/25 with 2.81” gauge Ring E-line Procedure 1. MIRU E-line/SL and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. a. Tree connection is 3-1/2” Bowen 2. Run tools to find fluid level. If fluid level is over the depth of the new perfs (5510’), then talk to the Operations Engineer about using Nitrogen or Sales gas pressure to push fluid away and setting a plug 3. If needed, RU Nitrogen truck a. Pressure up on well and push water back into formation. Use PT tool to confirm water level is below 5510’ 4. RIH with 3-1/2” CIBP and set at ±5,984’ MD. POOH 5. RU HC perf guns Well Prognosis Well: HVA-09 6. RIH and perforate the following intervals: Sand Top MD Btm. MD Top TVD Btm TVD Feet BEL_33 ±4,336’ ±4,346’ ±3,294’ ±3,303’ 10 BEL_41 ±5,019’ ±5,044’ ±3,843’ ±3,867’ 25 BEL_45 ±5,265’ ±5,275’ ±4,062’ ±4,073’ 10 BEL_46 ±5,308’ ±5,318’ ±4,102’ ±4,111’ 10 BEL_50 ±5,489’ ±5,509’ ±4,267’ ±4,286’ 20 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 h. Recent SITP pressures have not exceeded 500 psi proving existing perfs have been depleted and are not at original pressure 7. POOH 8. RDMO E-line 9. Turn well over to production Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations Well Name:Happy Valley #9 Field:Deep Creek Unit SCHEMATIC State:Alaska T-1B T-5 (Frac'd) BEL 84 BEL 83 BEL 78 BEL-120/135 BEL_92/99 T-7/8/10/17 Conductor: 13Ǫ", 72 ppf, L-80 to 73' Surface Casing: 7", 26 ppf, L-80, BTC-Mod to 3297' (6.276" ID) Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Production Liner: 3½", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' (2.992" ID) Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete Production Tubing: 3½", 9.2 ppf, L-80 IBT-Mod to 3083' Annulus loaded with 3% KCl brine plus corrosion inhibitor Completion Chemical injection sidepocket mandrel at 2495' (Macco SFO1- CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049'' Baker 80-40 seal assembly 3' of 4.00" OD seals Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP @ 6,302' 10/9/20 3-1/2" CIBP @ 6,865' w/ 47' of cement 9/29/19 API: 50-231-20027-00 AOGCC: 204-170 1104’ FSL, 1300’ FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3½" IBT Tree cxn - 3" Bowen cxn Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500'gross) was frac stimulated on12/18/04 with 99,700 lbs. of 20/40 Ottawa Sand in BJ Lightning-2000 gel. PBTD = 6302' TD = 8478' TOC @ 6,818' 09/30/19 Perf Data See page 2 TOC @ 3,300' (CBL on 11/1/04) Updated by Donna Ambruz 10-30-20 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Length Date Status BEL 78 6009’ 6015' 4741’ 4746 6 10/10/20 Open BEL 83 6059’ 6070’ 4785’ 4795’ 11 10/10/20 Open BEL 84 6106’ 6118’ 4827’ 4838’ 12 10/10/20 Open BEL_92 6321'6336'5019 5032 15 09/30/19 Isolated 10/9/20 BEL_99 6603'6611'5271 5278 8 09/30/19 Isolated 10/9/20 BEL_120 6885'6905'5523 5541 20 03/26/19 closed BEL_120 6902'6912'5538 5547 10 03/26/19 closed BEL_135 7142'7156'5755 5768 14 03/01/19 closed T-1B 7252'7258'5856 5861 6 03/01/19 closed T-5 7448'7469'6036 6056 21 12/17/05 closed T-5 7440'7470'6029 6057 30 11/09/05 closed T-5 7490'7500'6075 6084 10 11/08/04 closed T-7 7680'7700'6251 6270 20 11/08/04 closed T-8 7760'7786'6326 6350 26 11/08/04 closed T-10 7837'7867'6397 6425 30 11/08/04 closed T-17 8218'8237'6753 6771 19 11/05/04 closed Perforation Details Updated by Donna Ambruz 10-30-20 Well Name:Happy Valley #9 Field:Deep Creek Unit PROPOSED State:Alaska T-1B T-5 (Frac'd) BEL 33-50 BEL 84 BEL 83 BEL 78 BEL-120/135 BEL_92/99 T-7/8/10/17 Conductor:13Ǫ", 72 ppf, L-80 to 73' Surface Casing: 7", 26 ppf, L-80, BTC-Mod to 3297' (6.276" ID) Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Production Liner: 3½", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' (2.992" ID) Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete Production Tubing: 3½", 9.2 ppf, L-80 IBT-Mod to 3083' Annulus loaded with 3% KCl brine plus corrosion inhibitor Completion Chemical injection sidepocket mandrel at 2495' (Macco SFO1- CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049'' Baker 80-40 seal assembly 3' of 4.00" OD seals Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP @ ±5,984' TBD 3-1/2" CIBP @ 6,302' 10/9/20 3-1/2" CIBP @ 6,865' w/ 47' of cement 9/29/19 API:50-231-20027-00 AOGCC: 204-170 1104’ FSL, 1300’ FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3½" IBT Tree cxn -3" Bowen cxn Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs. of 20/40 Ottawa Sand in BJ Lightning-2000 gel. PBTD = 6302' TD = 8478' TOC @ 6,818' 09/30/19 Perf Data See page 2 TOC @ 3,300' (CBL on 11/1/04) Updated by CAH 02-20-25 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Length Date Status BEL 33 ±4336'±4346' ±3294' ±3303' 10 TBD PROPOSED BEL 41 ±5019' ±5044' ±3843' ±3867' 25 TBD PROPOSED BEL 45 ±5265' ±5275' ±4062' ±4073' 10 TBD PROPOSED BEL 46 ±5308' ±5318' ±4102' ±4111' 10 TBD PROPOSED BEL 50 ±5489' ±5509' ±4267' ±4286' 20 TBD PROPOSED BEL 78 6009’6015'4741’4746 6 10/10/20 Open BEL 83 6059’ 6070’ 4785’ 4795’11 10/10/20 Open BEL 84 6106’ 6118’ 4827’ 4838’12 10/10/20 Open BEL_92 6321'6336'5019 5032 15 09/30/19 Isolated 10/9/20 BEL_99 6603'6611'5271 5278 8 09/30/19 Isolated 10/9/20 BEL_120 6885'6905'5523 5541 20 03/26/19 closed BEL_120 6902'6912'5538 5547 10 03/26/19 closed BEL_135 7142'7156'5755 5768 14 03/01/19 closed T-1B 7252'7258'5856 5861 6 03/01/19 closed T-5 7448'7469'6036 6056 21 12/17/05 closed T-5 7440'7470'6029 6057 30 11/09/05 closed T-5 7490'7500'6075 6084 10 11/08/04 closed T-7 7680'7700'6251 6270 20 11/08/04 closed T-8 7760'7786'6326 6350 26 11/08/04 closed T-10 7837'7867'6397 6425 30 11/08/04 closed T-17 8218'8237'6753 6771 19 11/05/04 closed Perforation Details Updated by CAH 02-20-25 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. 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: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL HV A-09 (PTD 204-170) PLUG AND PERFORATING RECORD 10/10/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 2041700 E-Set: 34357 Abby Bell 12/09/2020 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 8,478 feet 6302; 6865 feet true vertical 6,999 feet N/A feet Effective Depth measured 6,302 feet 3,046 feet true vertical 5,002 feet 2,420 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 3,083' MD 2,444' TVD Packers and SSSV (type, measured and true vertical depth)Baker ZXP Pkr; N/A 3,046' MD 2,420' 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:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 0 Water-Bbl MD 73' 3,297' 8,476' 0 Oil-Bbl measured true vertical Packer 3-1/2" measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Deep Creek - HV Beluga/Tyonek GasN/A measured TVD Tubing Pressure 00 Happy Valley A-09 N/A FEE-CIRI/FEE-CIRI9 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-170 50-231-20027-00-00 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. 320-397 0 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 5,405' 0 6,997' 0 Representative Daily Average Production or Injection Data 73' 3,297' Conductor Surface Intermediate Production 10,530psi Casing Structural 13-3/8" 7" Length 7,240psi Collapse 5,410psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 10,160psi Burst 73' 2,584' 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 1:26 pm, Nov 04, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.04 13:15:43 -09'00' Taylor Wellman DSR-11/4/2020 SFD 11/5/2020RBDMS HEW 11/4/2020 Perforate Plug Perforations r: N2 gls 12-10-20 Rig Start Date End Date E-Line 10/9/20 10/10/20 10/09/2020 - Friday 10/10/2020 - Saturday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2500 psi high. TP - 700 psi. RIH w/GPT tool and tie into perf log. Ran a pre-perf log and also found FL at 4700'. Sent log to town and was on depth. Called Halliburton N2 to come out and push fluid into perfs and set plug. POOH into lubricator with GPT tool and wait on HLB N2 crew. Crew arrived and had PTW, JSA and SIMOPS with HLB E-Line. Rig up N2 hardline. Start cooling down the N2. Pressure test hard line and lubricator to 250 psi low and 4500 psi high, RIH w/GPT tool to 4800' and started pumping N2. Pump fluid into open perfs at 6321' starting at 4700' and ending up with FL at 6302' final rate and pressure was 1200 scfm/2770 psi. Shut N2 pump down and waited 10 min and pressure went to 2730. psi and no fluid rise. POOH. Will pressure tubing up to 2770 psi and wait depending on pressure we have below 2770 psi to make sure all fluid is gone before setting plug,. RIH w/2.75" OD CIBP and correlate to the GPT log. Run a correlation log, spot and set plug at 6300' with 2770 psi on tubing. Lost 250 lbs of line tension when plug set. Pick up 30' and go back down and tag plug. POOH. Setting tool looked good. Looks like good set. Rig down for the night. Closed both masters and swab. Left 2770 psi on top and bottom of plug. Will draw down tubing pressure to 800 psi for perf in the morning. PTW and JSA. Rig up lubricator, PT to 250 psi low and 3000 psi high. TP - 2000 psi. RIH w/2-3/8"x12' HC Razor, 5 spf. 60 deg phase and tie into plug log. Tag CIBP at 6302'. Run a correlation log and send to town. Get ok to perf from 6106' to 6118' with ~800 psi. Bled pressure down to 830 psi. Spotted and fired gun . After 5 min - 820 psi, 10 min - 800 psi and 15 min - 800 psi. POOH. All shots fired/Gun was Dry Gun #1. RIH w/2-3/8"x10' HC Razor, 5 spf. 60 deg phase and tie into plug log. Run a correlation log and send to town. Get ok to perf from 6060' to 6070' with 780 psi. Spot and fire gun w/780 psi on tubing. Pressure didn't move. Going to check gauge. POOH. All shots fired/Gun was Dry. Gun #2 Changed gauge. Same psi. RIH w/2-3/8"x6' HC Razor, 5 spf. 60 deg phase and tie into plug log. Run a correlation log and send to town. Get ok to perf from 6009' to 6015' with 760 psi. Spot and fire gun w/750 psi on tubing. After 5 min - 740', 10 min - 725 psi and 15 min - 729 psi. POOH. All shots fired/Gun was Dry. Gun #3. Rig down equipment and turn well over to field. Halliburton will leave some equipment here move some to Bart Pad to run GPT tool Monday. They plan to come out tomorrow and get N2 truck and rest of E-line equipment. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name HVA-09 50-231-20027-00-00 204-170 CIBP at 6300 ft Well Name:Happy Valley #9 Field:Deep Creek Unit SCHEMATIC State:Alaska T-1B T-5 (Frac'd) BEL 84 BEL 83 BEL 78 BEL-120/135 BEL_92/99 T-7/8/10/17 Conductor: 13Ǫ", 72 ppf, L-80 to 73' Surface Casing: 7", 26 ppf, L-80, BTC-Mod to 3297' (6.276" ID) Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Production Liner: 3½", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' (2.992" ID) Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete Production Tubing: 3½", 9.2 ppf, L-80 IBT-Mod to 3083' Annulus loaded with 3% KCl brine plus corrosion inhibitor Completion Chemical injection sidepocket mandrel at 2495' (Macco SFO1- CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049'' Baker 80-40 seal assembly 3' of 4.00" OD seals Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP @ 6,302' 10/9/20 3-1/2" CIBP @ 6,865' w/ 47' of cement 9/29/19 API: 50-231-20027-00 AOGCC: 204-170 1104’ FSL, 1300’ FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3½" IBT Tree cxn - 3" Bowen cxn Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs. of 20/40 Ottawa Sand in BJ Lightning-2000 gel. PBTD = 6302' TD = 8478' TOC @ 6,818' 09/30/19 Perf Data See page 2 TOC @ 3,300' (CBL on 11/1/04) Updated by Donna Ambruz 10-30-20 y 3-1/2" CIBP @ 6,302' 10/9/20 BEL 83 84 CIBP at 6302 ft BEL BEL 78 Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Length Date Status BEL 78 6009’ 6015' 4741’ 4746 6 10/10/20 Open BEL 83 6059’ 6070’ 4785’ 4795’ 11 10/10/20 Open BEL 84 6106’ 6118’ 4827’ 4838’ 12 10/10/20 Open BEL_92 6321'6336'5019 5032 15 09/30/19 Isolated 10/9/20 BEL_99 6603'6611'5271 5278 8 09/30/19 Isolated 10/9/20 BEL_120 6885'6905'5523 5541 20 03/26/19 closed BEL_120 6902'6912'5538 5547 10 03/26/19 closed BEL_135 7142'7156'5755 5768 14 03/01/19 closed T-1B 7252'7258'5856 5861 6 03/01/19 closed T-5 7448'7469'6036 6056 21 12/17/05 closed T-5 7440'7470'6029 6057 30 11/09/05 closed T-5 7490'7500'6075 6084 10 11/08/04 closed T-7 7680'7700'6251 6270 20 11/08/04 closed T-8 7760'7786'6326 6350 26 11/08/04 closed T-10 7837'7867'6397 6425 30 11/08/04 closed T-17 8218'8237'6753 6771 19 11/05/04 closed Perforation Details Updated by Donna Ambruz 10-30-20 p( ) ( ) p( ) ( ) g BEL 78 6009’ 6015' 4741’ 4746 6 10/10/20 Open BEL 83 6059’ 6070’ 4785’ 4795’ 11 10/10/20 Open BEL 84 6106’ 6118’ 4827’ 4838’ 12 10/10/20 Open Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Length Date Status 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): 8,478'none Casing Collapse Structural Conductor Surface 5,410psi Intermediate Production Liner 10,530psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell 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: 777-8503 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 6,999'6,818'5,463'~1,847 6,865' Baker ZXP Pkr; N/A 3,046' MD/2,420' TVD; N/A-N/A Perforation Depth TVD (ft):Tubing Size: COMMISSION USE ONLY Authorized Name: 10,160psi 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/FEE-CIRI9 204-170 50-231-20027-00-00 Happy Valley A-09 Deep Creek - HV Beluga/Tyonek Gas Length Size CO 553A/CO 540 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.2# / L-80 TVD Burst 3,083' MD 7,240psi 73' 2,584' 73' 3,297' 13-3/8" 7" 73' 3,297' Perforation Depth MD (ft): See Attached Schematic 3-1/2" 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: October 1, 2020 8,476'5,405' 3-1/2" 6,997' m n P s O t _ 66 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:49 pm, Sep 25, 2020 320-397 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.25 13:54:31 -08'00' Taylor Wellman SFD 9/25/2020 Plug Perforationss Perforate __N2__ 10-404 gls 9/28/20 DSR-9/28/2020Comm 9/29/2020 dts 09/29/2020 JLC 9/29/2020 RBDMS HEW 11/2/2020 Well: HVA-09 Date: 9/18/2020 Well Name:HVA-09 API Number:50-231-20027-00 Current Status:Shut-in Gas Producer Leg:N/A Estimated Start Date:10/1/20 Rig:E-line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:204-170 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:~ 2,375 psi @ 5,278’ TVD (Based on 0.45psi/ft. pressure gradient) Max. Potential Surface Pressure:~ 1,847 psi (Gas gradient @ 0.1psi/ft. to surface) Brief Well Summary Happy Valley A-09 is currently SI. The last perforation job unsuccessfully attempted to flow BEL 92 & BEL 99. Path forward is to continue perf’ing additional Beluga sands in order to get well back online. The purpose of this sundry/work is to add the below sands with contingencies to re-perforate the current open sands, and possibly shut off existing perfs (if necessary) Notes regarding Wellbore Condition -Min ID: 2.867” (tubing drift ID) -Max inclination: All <50 degrees -Last drifts: o 6865’ MD on 9/30/19 with 2.75” CIBP (no tag) o 6818’ MD (tag) on 10/1/20 with 8” x 2-3/8” perf gun Safety Concerns x Nitrogen Operations 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 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 W/ GPT tool and find fluid level. Consult with OE to see if we need to proceed to nitrogen displacement, or shoot as-is. 3. If needed, RU Nitrogen Truck and pressure up on well to push water back into formation. Use GPT tool to confirm water level is below interval to perf, ideally below plug set depth, if practical. e perf’ing additional Beluga sands Well: HVA-09 Date: 9/18/2020 4. If needed, RIH and set a 3-1/2” CIBP at ~6310’ MD (no cement needed) x Per Conservation Order 553A defines “The Happy Valley Beluga/Tyonek Gas Pool is defined as gas -bearing intervals common to, and correlating with, the interval between the measured depths of 2,246 and 10,046 feet in the Superior Happy Valley No. 31- 22 well.” x No cement is needed since all existing perfs and proposed perfs are within the same pool 5. Rig up perf guns and RIH 6. Perforate the sands bottom to top listed in the table below. Sand Top (MD) Bottom (MD)Top (TVD)Bottom (TVD) Length (ft.) BEL45 ±5267’±5276’±4066’±4074’9 BEL46 ±5309’±5325’±4104’±4119’16 BEL 50 ±5476’±5503’±4257’±4281’27 BEL 60 ±5737’±5753’±4496’±4510’16 BEL 70 ±5863’±5873’±4610’±4619 10 BEL 78 ±6008’±6016’±4740’±4747 8 BEL 83 ±6059’±6070’±4785’±4795’11 BEL 84 ±6106’±6118’±4827’±4838’12 BEL 92 6321’6336’(contingent reperf)15 BEL 99 6603’6611’8 a. Bleed WHP down per OE. 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. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. e. Record 5, 10, and 15 minute tubing pressures after firing 7. CONTINGENCY: If interval proves tight, a stim gun may be used to connectivity to formation 8. POOH, RD E-line. 9. Turn well over to production. E-line Procedure (Contingency): 1. If these zones produce sand and/or water and need to be isolated: 2. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 3. If needed, RIH with GPT and push away fluid with nitrogen to target depth 4. RIH and set 3-1/2” Liner Patch or set 3-1/2” CIBP above the zone. Attachments: 1. Actual Schematic 2. Proposed Well Schematic 3. Standard Well Procedure – N2 Operations BEL45 ±5267’±5276’±4066’±4074’9 BEL46 ±5309’±5325’±4104’±4119’16 BEL 50 ±5476’±5503’±4257’±4281’27 BEL 60 ±5737’±5753’±4496’±4510’16 BEL 70 ±5863’±5873’±4610’±4619 10 BEL 78 ±6008’±6016’±4740’±4747 8 BEL 83 ±6059’±6070’±4785’±4795’11 BEL 84 ±6106’±6118’±4827’±4838’12 BEL 92 6321’6336’15(contingent reperf) BEL 99 6603’6611’8 a. reperfs Well Name:Happy Valley #9 Field:Deep Creek Unit SCHEMATIC State:Alaska Conductor:13Ǫ", 72 ppf, L-80 to 73' Surface Casing:7", 26 ppf, L-80, BTC-Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Production Liner:3½", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg LitecretePBTD = 6818' TD = 8478' Production Tubing:3½", 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCl brine plus corrosion inhibitor Completion -Chemical injection sidepocket mandrel at 2495' (Macco SFO1-CI) with 1/4", 0.049" wall SS chemical injection line -Locator sub at 3049'' -Baker 80-40 seal assembly 13' of 4.00" OD seals -Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP at 6,865' w/ 47' of cement 9/29/19 Open Perfs: BEL92: 6,321' - 6,336' (6 spf, 9/30/19) BEL99: 6,603' - 6,611' (6 spf, 9/30/19) B120: 6885' - 6905' (6 spf, 03/26/19) B120: 6902' - 6912' (6 spf, 03/26/19) B135: 7142' - 7156' (6 spf, 03/01/19) T-1B: 7252' - 7258' (6 spf, 03/01/19) T-5: 7448' - 7469' (6 spf, 12/17/04) (Re-perf) T-5: 7440' - 7470' (6 spf, 11/9/05) T-5: 7490' - 7500' (6 spf, 11/8/04) T-7: 7680' - 7700' (6 spf, 11/8/04) T-8: 7760' - 7786' (6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11/8/04) T-17: 8218' - 8237' (6 spf, 11/5/04) API:50-231-20027-00 AOGCC: 204-170 1104’ FSL, 1300’ FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3½" IBT Tree cxn - 3" Bowen cxn Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Junk/Fill: -Tag fill @ 8327' on 1/31/05 Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs of 20/40 Ottawa Sand in BJ Lightning-2000 gel. B120 T-1B B135 T-5 T-7 T-10 T-8 T-17 BEL99 BEL92TOC @ 6,818' 09/30/19 Updated by DMA 10-04-19 Well Name:Happy Valley #9 Field:Deep Creek Unit PROPOSED SCHEMATIC State:Alaska Perfs per Sundry (TBD) BEL_92/99 BEL-120/135 T-1B T-5 (Frac'd) T-7/8/10/17 Conductor:13Ǫ", 72 ppf, L-80 to 73' Surface Casing: 7", 26 ppf, L-80, BTC-Mod to 3297' (6.276" ID) Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Production Liner: 3½", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' (2.992" ID) Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete Production Tubing: 3½", 9.2 ppf, L-80 IBT-Mod to 3083' Annulus loaded with 3% KCl brine plus corrosion inhibitor Completion Chemical injection sidepocket mandrel at 2495' (Macco SFO1- CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049'' Baker 80-40 seal assembly 3' of 4.00" OD seals Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP at 6,865' w/ 47' of cement 9/29/19 API:50-231-20027-00 AOGCC: 204-170 1104’ FSL, 1300’ FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3½" IBT Tree cxn - 3" Bowen cxn Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs. of 20/40 Ottawa Sand in BJ Lightning-2000 gel. PBTD = 6818' TD = 8478' TOC @ 6,818' 09/30/19 Perf Data See page 2 TOC @ 3,300' (CBL on 11/1/04) Contingent CIBP Updated by Ryan Rupert 9/21/20 TOC @ 3,300'@, (CBL on( 11/1/04) 3297 ft Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) Length Date Status BEL45 ±5267’ ±5276’ ±4066’ ±4074’ 9 Proposed BEL46 ±5309’ ±5325’ ±4104’ ±4119’ 16 Proposed BEL 50 ±5476’ ±5503’ ±4257’ ±4281’ 27 Proposed BEL 60 ±5737’ ±5753’ ±4496’ ±4510’ 16 Proposed BEL 70 ±5863’ ±5873’ ±4610’ ±4619 10 Proposed BEL 78 ±6008’ ±6016’ ±4740’ ±4747 8 Proposed BEL 83 ±6059’ ±6070’ ±4785’ ±4795’ 11 Proposed BEL 84 ±6106’ ±6118’ ±4827’ ±4838’ 12 Proposed BEL_92 6321 6336 15 09/30/19 Contingent shut-off BEL_99 6603 6611 8 09/30/19 Contingent shut-off BEL_120 6885 6905 20 03/26/19 closed BEL_120 6902 6912 10 03/26/19 closed BEL_135 7142 7156 14 03/01/19 closed T-1B 7252 7258 6 03/01/19 closed T-5 7448 7469 21 12/17/05 closed T-5 7440 7470 30 11/09/05 closed T-5 7490 7500 10 11/08/04 closed T-7 7680 7700 20 11/08/04 closed T-8 7760 7786 26 11/08/04 closed T-10 7837 7867 30 11/08/04 closed T-17 8218 8237 19 11/05/04 closed Perforation Details Updated by Ryan Rupert 9/21/20 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. Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE 8/20/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Happy Valley A-09 (PTD 204-170) Please include current contact information if different from above. Received by the AOGCC 08/24/2020 PTD: 2041700 E-Set: 33677 Abby Bell 08/24/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L Plug Perforations LJ Fracture Stimulate Li Pull Tubing Ll 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: N2 ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 204-170 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-231-20027-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE-CIRI/FEE-CIRI9 Happy Valley A-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Deep Creek - HV Beluga/Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 8478 feet Plugs measured 6865 feet true vertical 6999 feet Junk measured 8327 (fill) feet Effective Depth measured 6818 feet Packer measured 3046 feet true vertical 5463 feet true vertical 2420 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' Surface 3,297' 7" 3,297' 2,584' 7,240psi 5,410psi Intermediate Production Liner 5,405' 3-1/2" 8,476' 6,997' 10,160psi 10,530psi 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 3,083' MD 2,444' TVD Packers and SSSV (type, measured and true vertical depth) Baker ZXP Pkr; N/A 3,046' MD 2,420' 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 CasingPressure Tubing Pressure Prior to well operation: 0 0 0 0 686 Subsequent to operation: 10 0 0 0 649 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 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 LJ Gas ✓ WDSPL LJ 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: 319-386 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerna.hilcoro.com Authorized Signature: / Date: p/ (� f-- Lq ej Contact Phone: 777-8420 Form 10-404 Rerised 4/2017 13pMS./vr n 9 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date HVA -09 E -Line 1 50-231-20027-00 204-170 9/29/19 9/30/19 Daily Operations: 09/29/2019 -Sunday Sign in. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 700 psi. Chad had put 750 psi on well and took several fluid level shots and they were all within a few feet of each other yesterday. It showed fluid level at 7,550'. Decision was made to keep pressure on well and come out this morning and run in hole with GPT. RIH w/HLB GPT tool and tie into a GPT log. Found fluid level at 7,512'. Ran correlation log and send to town. POOH. I got a call from SLB N2 and they said they would be in town this afternoon. I let them know we didn't need them on this job but maybe on FC -6 Tuesday. RIH w/2.75" CIBP and tie into GPT tool. Set CIBP at 6,865' with 700 psi on tubing. Lost 100 Ib of line tension when plug set. Picked up 30' and went back down and tagged plug. POOH and tools looked ok. Good set. Make up 40' of 2-1/2" x 10' bailers and start mixing cement. Make 2 runs of 2-1/2" x 40' dump bailer filled with 16 ppg cement (35') and dump on top of plug at 6,865'. Est TOC at 6,830' and CIP at 2015 hrs. I have a cement sample in office at HV. Rig down lubricator and secure well. Will be on location at 0800 hrs in the morning to perforate. 09/30/2019 - Monday Sign in. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,000 psi high. TP - 700 psi.. RIH w/ 2- 3/8" x 8' HC Razor. 5 spf, 6 deg phase and tie into GPT tool. Tagged TOC at 6,818' (Should be 6,830'- probably stringer). Run correlation log and send to town. Told to change pert depth to 6,603' to 6,311'. Spotted and fired shot with 629 psi on scada. Good indication shots fired. Pressure stayed the same for 15 min. POOH. All shots fired and gun was dry. RIH w/ 2-3/8" x 15' HC Razor. 5 spf, 6 deg phase and tie into GPT tool. Run correlation log and send to town. Get ok to perf from 6,321' to 6,336' (15'). Spotted and fired shot with 617.4 psi on scada. Good indication shots fired. Pressure stayed the same for 15 min. POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. Rig down rest of equipment and head back to shop. W1 50-231-20027-00 'SCC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R1 3W, S.M. RT -THF: 16.4' lift threads - 31/.' IBT cxn - 3" Bowen cxn SCHEMATIC Production Tubinq: 3'/", 9.2 ppf, L-80, IBT-Mod to 3083' -Annulus loaded with 3% KCI brine plus corrosion inhibitor Chemical injection sidepocket mandrel at 2495' (Macco SFO1-CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049" Baker 80-40 seal assembly 13' of 4.00" OD seals Muleshoe at 3083' Jewelry Detail 3-1/2" CIBP at 6,865'w/ 47' of cement 9/29/19 Junk/Fill: - Tag fill @ 8327' on 1/31/05 max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440'- 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs of 20/40 Ottawa Sand in BJ Lightning -2000 gel. TOC @ BEL92 6,818- 09130/19 BEL99 B120 B135 T-1 B T-5 T-7 T-8 T-10 Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13'/", 72 ppf, L-80 to 73' Surface Casing' 7", 26 ppf, L-80, BTC -Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) BEL92: 6,321' - 6,336' (6 spf, 9/30119) ,BEL99: 6,603'- 6,611'(6 spf, 9/30/19) 8120: 6885'- 6905'(6 spf, 03/26/19) B120: 6902'- 6912'(6 spf, 03/26/19) B135: 7142'- 7156'(6 spf, 03/01/19) T-1 B: 7252'- 7258' (6 spf, 03/01/19) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re-perf) T-5: 7440'- 7470'(6 spf, 11/9/05) T-5: 7490'- 7500'(6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T-8: 7760'- 7786' (6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11/8/04) Production Liner: 3Yz", 9.2 ppf, L-80, IBT-Mod T-17 liner from 3071' -8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' FPBTD = 6818' Cemented with 189 bbl of 12.0 ppg Litecrete TD - 8478' Updated by DMA 10-04-19 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-09. Permit to Drill Number: 204-170 Sundry Number: 319-386 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, J sie�ielowski Commissioner DATED this %Z day of August, 2019. ,IBDMSd-� AUG 3 0 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 c;S ,I zzi I� 1. Type of Request: Abandon ❑ Plug Perforations 0 ' Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • 204-170 3. Address: 3800 Centerpoint Dr, Suite 1400 Straligraphic ❑ Service ❑ 6. API Number: Anchorage Alaska 99503 50-231-20027-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553A/CO 540 Will planned perforations require a spacing exception? YesNo ❑ ❑Q Happy Valley A-09 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE-CIRI/FEE-CIRI9 Deep Creek - HV BelugafFyonek Gas ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MO): Junk (MD): 8,478' 6,999' 8,411' 6,936' -1,778 N/A 8,327' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' Surface3,297' 7" 3,297' 2,584' 7,240psi 5,410psi Intermediate Production Liner 5,405' 3-1/2" 8,476' 6,997' 10,160psi 10,530psi 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 3,083' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP Pkr; N/A 3,046' MD/2,420' TVD; N/A -N/A 12. Attachments: Proposal Summary J Wellbore schematic El 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: September 2, 2019' OIL ❑ WINJ ❑ WDSPL ❑ ❑ Suspended 16. Verbal Approval: Date: GAS WAG ❑ GSTOR ❑ SPLUG ❑ 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. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: ctwocood([ahilcoro wm Date4Contact Phone: 777-8443 Authorized Signatur . : ,,,i -o \ g COMMISSIO SE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No RBDMS- AUG 3 0 2m Spacing Exception Required? Yes C1 No � Subsequent Form Required: C)' APPROVED BY Approved by: r 7L—/ COMMISSIONER THE COMMISSION Date: 22.' / '1 Z' fq V r\ I U IN • H -114 eu' ' /8ubmit Fonn and Form 10-463 Revised 4/2017 Approved application is valid for 12 months from he date of approval. I/ A chments in Duplicate /�% API: 50-231-20027-00 AOGCC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT -THF: 16.4' lift threads - 3%d' IBT cxn - 3" Bowen cxn SCHEMATIC Production Tubino7 3Yd", 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCI brine plus corrosion inhibitor chemical injection sidepocket mandrel at 2495' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049" Baker 80-40 seal assembly 13' of 4.00" OD seals Muleshoe at 3083' Junk/Fill: - Tag fill @ 8327' on 1/31/05 max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' - Screen out on T-5 (12/15/04) as soon as gelled fluid hit parts - The T-5 Sand (7440'- 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs of 20/40 Ottawa Sand in BJ Lightning -2000 gel. 8120 8135 T-1 B T-5 T-7 T-8 T-10 Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13'/:', 72 ppf, L-80 to 73' Surface Casing* 7", 26 ppf, L-80, BTC -Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) B120: 6885'-6905" (6 spf, 03/26/19) 8120: 6902'-6912'(6 spf, 03/26/19) 8135: 7142'-7156'(6 spf, 03/01/19) T-18: 7252'-7258'(6 spf, 03/01/19) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re -pert) T-5: 7440'- 7470'(6 spf, 11/9105) T-5: 7490'- 7500'(6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8104) T-8: 7760' - 7786' (6 spf, 11 /8/04) . T-10: 7837'- 7867'(6 spf, 11/8/04) T-17 Production Liner: 3%', 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' PBTD = 8411' Cemented with 189 bbl of 12.0 ppg Litecrete TO = 8478' HVA -9 Schematic 04-22-19 Updated by: DMA Well Name Field PROPOSED SCHEMATIC State API: 50-231-20027-00 AOGCC: 204.170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT -THF: 16.4' Tbg lift threads - 3'/2" IBT Tree un - 3" Bowen un Production Tubina, 3%2", 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Chemical injection sidepocket mandrel at 2495' (Matto SF01-CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049" Baker 80-40 seal assembly 13' of 4.00" OD seals Muleshoe at 3083' at +6,665' w/ 35' of cement un Fill: - Tag fill @ 8327' on 1/31/05 Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440'- 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs of 20/40 Ottawa Sand in BJ Lightning -2000 gel. Happy Valley #9 Deep Creek Unit Alaska Conductor: 13'%", 72 ppf, L-80 to 73' Surface Casino: 7", 26 ppf, L-80, BTC -Mod to 329T Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) BEL92 TOC @ BEL99 B120 8135 T -IB T-5 T-7 T-8 T-10 BEL92: +6,321'- +6,336'(6 spf, Proposed) BEL99: +6,601' -+6,609' (6 spf, Proposed) B120: 6885' - 6905' (6 spf, 03/26/19) 8120: 6902'- 6912'(6 spf, 03/26/19) 8135: 7142'- 7156'(6 spf, 03/01/19) T-1 B: 7252'- 7258'(6 spf, 03/01/19) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re-perf) T-5: 7440'- 7470'(6 spf, 11/9/05) T-5: 7490'- 7500' (6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T-8: 7760'- 7786'(6 spf, 11/8104) T-10: 7837'- 7867'(6 spf, 11/8104) Production Liner: 3112", 9.2 ppf, L-80, IBT-Mod T-17 liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 8040 sealbore at 3046' PBTD = 8411' Cemented with 189 bbl of 12.0 ppg Litecrete TD = 8478' HVA -9 Proposed Schematic 08-14-19 Updated by: CMT 50-231-20027-00 !CC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT -THF: 16.4' Tbg lift threads - 31/" IBT Tree cxn - 3" Bowen un Production Tubing: 3'/", 9.2 ppf, L-80, IBT-Mod to 3083' -Annulus loaded with 3% KCI brine plus corrosion inhibitor - Chemical injection sidepocket mandrel at 2495' (Macro SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' CIBP at +6,865'w/ 35' of cement Junk/Fill: -Tag fill @ 8327' on 1/31/05 i irface Casing: 7", 26 ppl, L-80, BT,/ with Mod to of 12 Cmnt with 137 bbl of 12.8 ppg lead and /17 bbl of 15.8 ppg tail "G". performed two cement top -jobs (51 bbl and 4 bbl) BEL92 TOC @ /BEL9 B135 T-1 B T-5 max hole angle = 50.5 deg at 3595' T-7 KOP = 205' BEL99:+69 110se '-+6912' (6 spf, Pred) B120: 5'- 6905'(6 spf, 03/26/19) B120: 6902'- 6912'(6 spf, 03/26/19) B135: 7142'- 7156'(6 spf, 03/01/19) T-1 B: 7252'- 7258' (6 spf, 03/01119) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re -pert) T-5: 7440'- 7470'(6 spf, 1119/05) T-5: 7490' - 7500' (6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T-8: 7760'- 7786'(6 spf, 11/8/04) T-10: 7837'- 7867'(6 spf, 11/8/04) 717. R91 R1 _ R9R7' 1A eM 11 JAMA1 max doglegs = 6.4 deg/100' at 298' T-8 8.0 deg/100' at 13 ' 5.2 deg/100' at 1 00' T-10 Production Liner: 3%", 9.2 ppf, L-80, IBT-Mod T-17 liner from 3071' - 8476' ttimulation: Baker ZXP packer, Flexlock liner hanger & Screen out on T-5 (12/ 5/04) as soon as 80-40 sealbore at 3046' felled fluid hit Paris Cemented with 189 bbl of 12.0 ppg Litecrete The T-5 Sand (744 - 7500' gross) was frac PBTD = 8411' timulated on 12/1 04 with 99,700 lbs of TO = 8478' 0/40 Ottawa Sa in BJ Lightning -2000 gel. HVA -9 Proposed Schematic 08-14-19 Updated by: CMT Well Name: Happy Valley #9 Field: Deep Creek Unit PROPOSED SCHEMATIC State: Alaska Conductor: 13'/.", 7 ppf, L-80 to 73' , Production Tubing: 3'/", 9.2 ppf, L-80, IBT-Mod to 3083' -Annulus loaded with 3% KCI brine plus corrosion inhibitor - Chemical injection sidepocket mandrel at 2495' (Macro SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' CIBP at +6,865'w/ 35' of cement Junk/Fill: -Tag fill @ 8327' on 1/31/05 i irface Casing: 7", 26 ppl, L-80, BT,/ with Mod to of 12 Cmnt with 137 bbl of 12.8 ppg lead and /17 bbl of 15.8 ppg tail "G". performed two cement top -jobs (51 bbl and 4 bbl) BEL92 TOC @ /BEL9 B135 T-1 B T-5 max hole angle = 50.5 deg at 3595' T-7 KOP = 205' BEL99:+69 110se '-+6912' (6 spf, Pred) B120: 5'- 6905'(6 spf, 03/26/19) B120: 6902'- 6912'(6 spf, 03/26/19) B135: 7142'- 7156'(6 spf, 03/01/19) T-1 B: 7252'- 7258' (6 spf, 03/01119) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re -pert) T-5: 7440'- 7470'(6 spf, 1119/05) T-5: 7490' - 7500' (6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T-8: 7760'- 7786'(6 spf, 11/8/04) T-10: 7837'- 7867'(6 spf, 11/8/04) 717. R91 R1 _ R9R7' 1A eM 11 JAMA1 max doglegs = 6.4 deg/100' at 298' T-8 8.0 deg/100' at 13 ' 5.2 deg/100' at 1 00' T-10 Production Liner: 3%", 9.2 ppf, L-80, IBT-Mod T-17 liner from 3071' - 8476' ttimulation: Baker ZXP packer, Flexlock liner hanger & Screen out on T-5 (12/ 5/04) as soon as 80-40 sealbore at 3046' felled fluid hit Paris Cemented with 189 bbl of 12.0 ppg Litecrete The T-5 Sand (744 - 7500' gross) was frac PBTD = 8411' timulated on 12/1 04 with 99,700 lbs of TO = 8478' 0/40 Ottawa Sa in BJ Lightning -2000 gel. HVA -9 Proposed Schematic 08-14-19 Updated by: CMT R nilcarn Alaska, M Well Prognosis Well: HVA -9 Date: 8/14/19 Well Name: HVA -9 API Number: 50-231-20027-00-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: 9/2/2019 Rig: E -line Reg. Approval Req'd? 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-170 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) AFE Number Current Surface Pressure: Maximum Expected BHP: Max. Potential Surface Pressure: Brief Well Summary -648 psi -2,306 psi at 5,276' TVD `1,778 psi at 5,276' TVD (Based on 8/1/19 SCADA) (Based on normal gradient) (Based on expected BHP and gas gradient to surface (0.10 psi/ft)) HVA -9 was drilled in September 2004 and was originally completed in the T-17 sand which IP'd at 550 MCFD. In November 2004 four additional sands were added which increased production to 950 MCFD. In December 2004 the T6 was frac'd with 100,000 lbs. of 20/40 Ottawa sand which increased the rate to 1.6 MMCFD. In March 2019 the T-16, BEL135 and BEL120 sands were perforated but did not add any rate. � r The purpose of this work/sundry is to isolate all existing perforations and perforate the BEL92 and BEL99 Sands. Notes Regarding Wellbore Condition The well is currently shut in. . MIRU Slickline and make dummy gun run prior to performing work. Safety Concerns • Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people 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 / 3,000 psi High. a. Tree connection is 3-1/2" Bowen. 2. RIH with GPT tool and find fluid level. If fluid level is over the depth of the new perfs, then talk to the Operations Engineer about using Nitrogen and setting a plug. 3. RU Nitrogen truck. 4. If needed, pressure upon well and push water back into formation. Use GPT tool to confirm Water level is below interval to perf. 5. RIH with 3-1/2" CIBP and set at 6,865' MD. Dump bail 35' of cement on top. POOH H Hilmm AI.Aa, LG 6. RU 2-3/8" HC, 6 SPF, 602 phasing perf guns. 7. RIH and perforate the following intervals: Zone Sands Top (MD) Btm(MD) Top (TVD) Btm (TVD) FT Beluga 92 ±6,321' ±6,336' ±5,018' ±5,031' ±15' Beluga 99 ±6,601' ±6,609' ±5,269' ±5,276' ±8' Well Prognosis Well: HVA -9 Date: 8/14/19 a. Pressure up well to 500 psi before perforating. b. Proposed perfs 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. Use Gamma/CCL to correlate. e. Spacing allowance is based on CO 553A, no restrictions in Beluga Gas Pool f. Record tubing pressure before and after each perforating run. g. Record 5, 10 and 15 minute pressures after firing guns. 8. POOH. 9. RDMO E -line. 10. Turn well over to production. E -line Procedure (Contingency): 1. if these zones produce sand and/or water and need to be isolated. 2. MIRU E -line, PT lubricator to 250 psi Low / 3,000 psi High. 3. RIH and set 3-1/2" Casing Patch or set CIBP above the zone and dump 35' of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure — N2 Operations 11 STANDARD WELL PROCEDURE Hilcorl, 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 FINAL vl Page 1 of 1 Davies, Stephen F (CED) From: Christina Twogood - (C) <ctwogood@hilcorp.com> Sent: Thursday, August 22, 2019 11:28 AM To: Davies, Stephen F (CED) Cc: Ted Kramer Subject: RE: [EXTERNAL] Happy Valley A-09 (PTD 204-170; Sundry 319-386) - Question Attachments: HVA -9 Proposed Schematic 08-14-19.pdf Good Morning Steve, Apologies for the discrepancy. The depths in the E -line procedure are correct. I have amended the Proposed Schematic and attached this for your reference. Thank you, Christina Twogood Operations Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w)907-777-8443 (c) 907-378-7323 From: Davies, Stephen F (CED)[mailto:steve.davies@alaska.gov) Sent: Thursday, August 22, 2019 11:09 AM . To: Christina Twogood - (C) <ctwogood@hilcorp.com> Subject: [EXTERNAL] Happy Valley A-09 (PTD 204-170; Sundry 319-386) - Question Christina, Quick question: In Hilcorp's sundry application, the proposed perforation depths for the Beluga 92 sand shown on the Proposed Schematic drawing don't match those in the table within the E -Line procedure (6885' to 6905' versus 6321' to 6336'). Which are correct? Thank you, 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.aov. The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 2 3 2019 1. Operations Abandon Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Li aljkl1jaL4k)jn LJ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ �rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 204-170 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-231-20027-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE-CIRI/FEE-CIRI9 Happy Valley A-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Deep Creek - HV Beluga/Tyonek Gas 11. Present Well Condition Summary: Total Depth measured 8478 feet Plugs measured N/A feet true vertical 6999 feet Junk measured 8327 (fill) feet Effective Depth measured 8411 feet Packer measured 3046 feet true vertical 6936 feet true vertical 2420 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' Surface 3,297' 7" 3,297' 2,584' 7,240psi 5,410psi Intermediate Production Liner 5,405' 3-1/2" 8,476' 6,997' 10,160psi 10,530psi 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 3,083' MD 2,444' TVD Packers and SSSV (type, measured and true vertical depth) Baker ZXP Pkr; N/A 3,046' MD 2,420' 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: 0 216 0 0 94 Subsequent to operation: 0 39 0 0 96 14. Attachments (r mored per 20 A C 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory[:] Development ❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas r 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: 319-044 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer/d)hilcom.com Authorized Signature: Date:2Z I e1 Contact Phone: 777-8420 Form 10404 Revised 4/2017 88DMS�APR 2 4 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date HVA-09 E-Line 50-231-20027-00 1 204-170 2/28/19 3/26/19 Daily Operations: 02/28/2019 - Thursday PTW and JSA. Spot and rig up lubricator. PT to 250 psi low and 3,000 psi high. RIH w/ 2.50" x 5' bailer and tag bottom at 8,272' KB. Sticky on bottom. Acts like fluid level at 7,500'. POOH. Well flow 91 mcfd at 94 psi. NOTE: Flapper on bailer bottom was stuck open so bailer was empty. RIH with 2-3/8" x 15' spent pert gun (as a dummy) down to 7,600'. Did not set down or have any trouble. Still looks like fluid level at 7,500'. Deepest proposed pert is at 7,257'. POOH. Well flow 91 mcfd at 94 psi. Rig down and move to HVB-12. 03/01/2019 - Friday PTW and JSA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,000 psi high. TP - 612 psi. RIH w/GPT tool and tie into log sent by Taylor. Found fluid level at 7,480' with 611.3 psi. Ran log and send to town. POOH. RIH w/ 2-3/8" x 6' HC, 5 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Town sent back new perf depth (1' down) from 7,252' to 7,258'. Spot and fire gun with 611 psi. 5 min - 612.48 psi, 10 min 611.85 psi and 15 min - 609 psi. POOH all shots fired and gun was wet. Fired gun at 2018 hrs. RIH w/ 2-3/8" x 14' HC, 5 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Town sent back new perf depth (2' down) from 7,142' to 7 156. Spot and fire gun with 606 psi. After 5 min - 607.9 psi, 10 min - 608.2 psi and 15 min - 607.9 psi. POOH. All shots fired and gun was dry. Fired gun at 2200 hrs. Rig down and turn well back over to field. TP - 603.2 psi 03/26/2019-Tuesday Spot equipment. PTW and JSA. Put new cable head on. Rig up lubricator. PT to 250 psi low and 3,000 psi high. Pressure well up to 780 psi. RIH w/GPT tool and tie into OHL. Found fluid level at 7,086'w/780 psi on tubing. Run correlation log and send to town. POOH. RIH w/ 2-3/8" x 10' HC, 5 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Log was off 2-3' so town changed perf depth to 6,902'to 6,912' using same log. Spotted and fired shot w/750 psi on gauge. Field was trending on scada at SD. Pressure stayed the same after 15 min on gauge. POOH. All shots fired and gun was dry. Gun fired at 1653 hrs. RIH w/ 2-3/8" x 20' HC, 5 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 6,885' to 6,905'. Spot and fire gun with 800 psi on gauge. Stayed at 800 psi for 15 min. POOH. Scada was reading 790.7 psi. All shots fired and gun was dry. Fired gun at 1856 hrs Rig down lubricator and equipment and turn well back over to field. 50-231-20027-00 SCC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R1 3W, S.M. RT -THF: 16.4' lift threads - 3'/2" IBT cxn - 3" Bowen cxn 3%", 9.2 ppf, L-80, SCHEMATIC -Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection sidepocket mandrel at 2495' (Macco SFOt-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 8040 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' Junk/Fill: - Tag fill @ 8327' on 1/31/05 Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' yen out on T-5 (12/15/04) as soon as fluid hit perfs T-5 Sand (7440'- 7500' gross) was frac ated on 12/18/04 with 99,700 lbs of Ottawa Sand in BJ Lightning -2000 gel. /y 8120 B135 UU T -1B T-5 T-7 T-8 T-10 Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13%", 72 ppf, L-80 to 73' ce Casino: 7", 26 ppf, L-80, BTC -Mod to 3297' with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". rmed two cement top -jobs (51 bbl and 4 bbl) B120: 6885'-6905" (6 spf, 03/26/19) B120: 6902'-6912'(6 spf, 03/26/19) B135: 7142'-7156'(6 spf, 03/01/19) T-1 B: 7252'-7258' (6 spf, 03/01/19) W Pf T-5: 7448'- 7469'(6 spf, 12/17/04) (Re -pert) T-5: 7440'- 7470' (6 spf, 11/9/05) T-5: 7490'- 7500'(6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T-8: 7760'- 7786'(6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11/8/04) T-17: 8218'- 8237'(6 spf, 11/5/04) Production Liner: 3%", 9.2 ppf, L-80, IBT-Mod T-17 liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' PBTD = 8411' Cemented with 189 bbl of 12.0 ppg Litecrete TO = 8478' HVA -9 Schematic 04-22-19 Updated by: DMA Re April 23, 2019 Commissioners Cathy Foerster and Dan Seamount Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Ste 100 Anchorage, AK 99501 Re: Courtesy notice of new BPXA Vice President of Operations Dear Commissioners: BP Exploration (Alaska) Inc. PO. Box 196612 Anchorage, AK 99519-6612 APR 2 5 ?^tq AOC; U I am pleased to inform you that Mr. Donnie Brown has assumed my role as Vice President of Operations for BP Exploration (Alaska) Inc. ("BPXA"). Mr. Brown comes to this role with extensive leadership experience in safety and operational matters, and I am confident that he will develop an excellent relationship with you and your staff. For your convenience I am including Mr. Brown's contact information below: Donnie Brown Vice President, Operations BP Exploration (Alaska) Inc. 900 East Benson Blvd Anchorage, Alaska 99508 907-564-5615 donnie.brown@bp.com Please do not hesitate to contact either myself or Mr. Brown if you have any questions. With kindest regards, Neil Loader cc: Mr. Jim Regg AOGCC Petroleum Engineer Mr. Donnie Brown BPXA Vice President, Operations Ms. Krissell Crandall BPXA Director, Regulatory Compliance and Environment THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Alaska Oil and Gas Conservation Commission Bo York Operation Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Deep Creek Field, Beluga/Tyonek Gas Pool, Happy Valley A-09 Permit to Drill Number: 204-170 Sundry Number: 319-212 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Wv W.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, Daniel T. Seamount, Jr. Commissioner DATED thisday f April, 2019. RBDMS& APR 2 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 APR 2 3 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ After Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 204-170 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-231-20027-00-00 ' 7. If perforating: A, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553A Will planned perforations require a spacing exception? Yes ❑ No [Z Happy Valley A-09 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE-CIRI/FEE-CIRI9 Deep Creek- 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): 8,478' 6,999' 8,411' 6,936 -2,256psi N/A 8,327' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' Surface 3,297' 7" 3,29T 2,584' 7,240psi 5,410psi Intermediate Production Liner 5,405' 3-1/2" 8,476' 6,997' 10,160psi 10,530psi Perforation Depth MD I Perforation Depth TVD (ft): Tubing Size: Tubing Grade, Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2# / L-80 3,083' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP Pkr; N/A 3,046' MD/2,42U TVD; N/A -N/A 12. Attachments: Proposal Summary ❑j 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: Commencing Operations: May 10, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS Q 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. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerlrDhilcoro.com Contact Phone: 777-8420 9 Authorized SignatureDate: r� cOMMlss N USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L^ ' 2 Plug Integrity ❑ BOP Test E]Mechanical Integrity Test E] Location Clearance Other: -4131)MS,hf�/ APR 2 6 2019 Post Initial Injection MIT Req'd? Yes ❑ Na ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 6 / O —YO4 / APPROVED BY �-•/ZS, / Approved by: COMMISSIONER THE COMMISSION Date: N(1 Submit Form and Form 10-40 jRevis��4/2017 Approved applicatio � isvir�p fir &f rN fA �e date of approval. �/�/ Attachments in Duplicate U Hll.rV Aleskw M Well Prognosis Well: HVA -9 Date:4/22/19 Well Name: HVA -9 API Number: 50-231-20027-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 5/10/19 Rig: N/A Reg. Approval Req'd? 10-403 Sundry Number: ±19 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-170 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number Estimated Bottom Hole Pressure: Current Max. Surface Pressure: Max. Potential Surface Pressure: Brief Well Summary: -2,935 psi at 6,778' TVD (Assumed 0.43 psi/ft) —500 psi (Based on 4 hr. SI) —2,256 psi (Based on 0.10 psi/ft gas gradient to surface) HVA -9 was drilled in September 2004 and was originally completed in the T-17 sand which IP'd at 550 MCFD. November 2004, four additional sands were added which increased production to 950 MCFD. In December 2004, the T6 was fracd with 100,000 lbs. of 20/40 Ottawa sand. This stimulation increased the rate to 1.6MMscfd. In March of 2019 the T-113, Bel 135 and BEL 120 were added but did not add any rate. Objective: • Perforate the T-76, T-10, T-17, and T-19 intervals. Notes Regarding Wellbore Condition • The well is currently flowing = 91 MCFD at 94 psig. • MIRU slickline and make dummy gun run prior to performing work. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 250 psi low/3,000 psi high. 2. PU Perf guns, RIH and Log on depth. Perforate the following intervals: Sands Top (MD) Btm (MD) FT T-713 ±7,656' ±7,665' ±9 T-10 ±7,867 ±7,887 ±20 T-17 ±8,199' ±8,218' ±19 T-19 ±8,408' ±8,420' ±12 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Use Gamma/CCL/ to correlate. d. Spacing allowance is based on CO 553A, no restrictions in Beluga Gas Pool. e. If interval is wet, it will be permanently isolated with a casing patch and/or plug. f. Record 5, 10, 15 min. pressures after firing guns. In 3. RDMO a -line. 4. Turn well over to production to test. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Well Prognosis Well: HVA -9 Date:4/22/19 50-231-20027-00 CC:204-170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT -THF: 16.4' lift threads - 31/.' IBT cxn - 3" Bowen cxn 3'/d', 9.2 ppf, L-80, Well Name: Happy Valley #9 Field: Deep Creek Unit SCHEMATIC State: Alaska - Annulus loaded with 3% KCI brine plus rosion inhibitor Chemical injection sidepocket mandrel at 2495' (Macro SFO1-CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049" Baker 80-40 seal assembly 13' of 4.00" OD seals Muleshoe at 3083' Junk/Fill: - Tag fill @ 8327' on 1/31/05 max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Screen out on T-5 (12/15/04) as soon as elled fluid hit perfs The T-5 Sand (7440'- 7500' gross) was frac timulated on 12/18/04 with 99,700 lbs of 0/40 Ottawa Sand in BJ Lightning -2000 gel. B120 B135 T -1B T-5 T-7 T-8 T-10 Conductor: 13'/.", 72 ppf, L-80 to 73' Surface Casino: 7", 26 ppf, L-80, BTC -Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) 8120: 6885'-6905" (6 spf, 03/26/19) B120: 6902'-6912'(6 spf, 03/26/19) B135: 7142'-7156'(6 spf, 03/01/19) T -1B: 7252'-7258'(6 spf, 03/01/19) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re -pert) T-5: 7440' - 7470' (6 spf, 11/9/05) T-5: 7490'- 7500'(6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T-8: 7760'- 7786'(6 spf, 11/8/04) T-10: 7837'- 7867'(6 spf, 11/8/04) T-17: 8218'- 8237'(6 spf, 11/5/04) Production Liner: 31/2', 9.2 ppf, L-80, IBT-Mod T-17 liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' PBTD = 8411' Cemented with 189 bbl of 12.0 ppg Litecrete TD HVA -9 Schematic 04-22-19 Updated by: DMA 31-20027-00 204-170 1104' FSL, 1300' FEL Sec22, T2S, R1 3W, S.M. -THF: 16.4' lift threads - 31/2' 1 B cxn - 3" Bowen cxn Well Name: Happy Valley #9 Field: Deep Creek Unit PROPOSED SCHEMATIC State: Alaska Production Tubing: 3'/z', 9.2 ppf, L-80, IBT-Mad to 3083' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection sidepocket mandrel at 2495' (Macco SF01-CI)with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' Junk/Fill: - Tag fill @ 8327' on 1/31/05 Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Stimulation: - Screen out on T-5 (12/15/04) as soon as gelled fluid hit perfs - The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 lbs of 20/40 Ottawa Sand in BJ Lightning -2000 gel. 8120 B135 T-1 B T-5 T-7 T -7B T-8 T-10 Conductor: 13%", 72 ppf, L-80 to 73' Surface Casino: 7", 26 ppf, L-80, BTC -Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) B120: 6885'-6905" (6 spf, 03/26/19) B120: 6902'-6912'(6 spf, 03/26/19) B135: 7142'-7156'(6 spf, 03/01/19) T-1 B: 7252'-7258'(6 spf, 03/01/19) T-5: 7448'- 7469'(6 spf, 12/17/04) (Re-perf) T-5: 7440'- 7470'(6 spf, 11/9/05) T-5: 7490'- 7500'(6 spf, 11/8/04) T-7: 7680'- 7700'(6 spf, 11/8/04) T -7B: ±7656'-±7665'(±9' Proposed) T-8: 7760'- 7786'(6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11 /8/04) T-10: ±7867'-±7887' (±20' Proposed) T-17: ±8199'-±8218' (119' Proposed) T-17: 8218'- 8237'(6 spf, 11/5/04) T-19: ±8408'-±8420' (±12' Proposed) T-17 Production Liner: 31/2', 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' T-19 Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' PBTD = 8411' Cemented with 189 bbl of 12.0 ppg Litecrete TD = 8478' HVA -9 Proposed Schematic 04-22-19 Updated by: DMA 10,000,000 1,000,000 t C O n 100,000 LL � o N 10,000 co _ O O w o A m a t7 ti c 1,000 U 7 U 100 3 O L 10 HILCORP ALASKA LLC, HAPPY VALLEY A-09 (204-170) DEEP CK, HV BELUGA/TYONEK GAS Monthly Production Rates aaaaa��ar_aa�aaaaa� aaaaa�aaaaa��aaaaa�aaaaa�aaaaa�� aaaaa��C� �aaaaa�aaaaa�aaaaa�ai-�.w��r '�..... a�aaa�aaaaa�aaaa�Oaaaaaa� aaa�a�aaaaa�aaaaa�aaaaa�� aaaa�aaaaa�aaaaa� aaa�aaaaa�aaaaa�aaa� a�aaaaa�: � 110000001 Jan -2005 Jan -2010 Jan -2015 Produced Gas (MCFM) • GOR —f- Produced Water (BOPM) —o-- Produced Oil (ROPM) 10,000,000 W v 1,000,000 O_ O 100,000 m 3 0 3 S 10,000 0 W m 1,000 0 mm 100 N 0 0 10 s — 1 Jan -2020 SPREADSHEET_2041700_Happy_Va Iley_A-09_Prod-I nject_Cu Nes_W el I_Gas_V 120_20190424.xIsx 4/24/2019 THE STATE OIALASKA 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-09 Permit to Drill Number: 204-170 Sundry Number: 319-044 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www. a o gc c. o laska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this -S day of February, 2019. SCANNED FEB 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JAN 3 1 2019 HOGCC 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: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development El- Stratigraphic ❑ Service ❑ 204-170 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-231-20027-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 553A , Will planned perforations require a spacing exception? Yes ❑ No E Happy Valley A-09 9. Property Designation (Lease Number): 10. Field/Pool(s): ' FEE-CIRI/FEE-CIRI9 Deep Creek - 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): 8,478' • 6,999' 8,411' 6,936'-2,256psi 8,327' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' Surface 3,297' 7" 3,297' 2,584' 7,240psi 5,41 Ops! Intermediate Production Liner 5,405' 3-1/2" 8,476' 6,997' 10,160psi 10,530psi 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 3,083' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker ZXP Pkr; N/A 3,046' MD/2,420' TVD; N/A -N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑2 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 14, 2019 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. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcom.com Contact Phone: 777-8420 Authorized Signature: Date: '3&.% I-Vavq COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 17 1 9, J IVI—�� I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑/ / Spacing Exception Required? Yes E]6 No Q Subsequent Form Required: V —q Q l APPROVED BY COMMISSIONER THE COMMISSION Date: ` 2-[,5 Approved by:Al X\y^• 10-403 Revised 4/20 �j/ Z. s eve Approved applicatio j{ ��aaaMMM �' �r o Ai! it t �" t ■ 1 ?A7 Submit Form and r Attachment Duplicate g EB 0 5 2019 U Hilcom Alaska, Lb Well Prognosis Well: HVA -9 Date: 1/29/19 Well Name: HVA -9 API Number: 50-231-20027-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: 2/14/19 Rig: N/A Reg. Approval Req'd? 10-403 Sundry Number: ±6 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 204-170 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number Estimated Bottom Hole Pressure: Current Max. Surface Pressure: Max. Potential Surface Pressure: Brief Well Summary: —2,935 psi at 6,778' TVD (Assumed 0.43 psi/ft) —500 psi (Based on 4 hr. SI) —2,256 psi (Based on 0.10 psi/ft gas gradient to surface) HVA -9 was drilled in September 2004 and was originally completed in the T-17 sand which IP'd at 550 MCFD. In November 2004, four additional sands were added which increased production to 950 MCFD. In December 2004, the T6 was fracd with 100,000 lbs. of 20/40 Ottawa sand. This stimulation increased the rate to 1.6MMscfd. Objective: • Perforate the T-113, BEL 135, and the BEL 120 intervals. Notes Regarding Wellbore Condition • The well is currently flowing = 91 MCFD at 94 psig. • MIRU slickline and make dummy gun run prior to performing work. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricatorto 250 psi low/3,000 psi high. 2. PU Perfguns, RIH and Log on depth. Perforate the following intervals: Sands Top (MD) Btm (MD) FT BEL 120 ±6,885' ±6,915' ±30 BEL 135 ±7,140' ±7,154' ±14 T-113 ±7,251' ±7,257' ±6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact pert intervals. c. Use Gamma/CCL/ to correlate. 7 d. Spacing allowance is based on CO 553A, no restrictions in Beluga Gas Pool. e. If interval is wet, it will be permanently isolated with a casing patch and/or plug. f. Record 5, 10, 15 min. pressures after firing guns. 3. RDMO e -line. U Hilcorn Alaska, LL 4. Turn well over to production to test. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Well Prognosis Well: HVA -9 Date: 1/29/19 50-231-20027-00 ;CC: 204170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT -THF: 16.4' Tbg lift threads - 3Y:" IBT Tree cxn - 3" Bowen cxn 3Y2', 9.2 ppf, L-80, -Annulus loaded with 3% KCI brine plus corrosion inhibitor Chemical injection sidepocket mandrel at 2495' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line Locator sub at 3049" Baker 8040 seal assembly 13' of 4.00" OD seals Muleshoe at 3083' Junk/Fill: - Tag fill @ 8327' on 1/3 max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' Screen out on T-5 (12/15/04) as soon as elled fluid hit perfs The T-5 Sand (7440'- 7500' gross) was frac timulated on 12/18/04 with 99,700 lbs of 0/40 Ottawa Sand in BJ Lightning -2000 gel. Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13'W, 72 ppf, L-80 to 73' Surface Casinc: 7", 26 ppf, L-80, BTC -Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) T-5: 7448'-7469'(6 spf, 12/17/04) (Re -perry T-5: 7440' - 7470' (6 spf, 11 /9/05) - T-5: 7490' - 7500' (6 spf, 11 /8/04) - T-7: 7680' - 7700' (6 spf, 11 /8/04) T-8: 7760' - 7786' (6 spf, 11 /8/04) T-10: 7837' - 7867' (6 spf, 11 /8/04) T-17: 8218'- 8237' (6 spf, 11/5104)' J Production Liner: 3Y:', 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' FCemented with 189 bbl of 12.0 ppg Litecrete PBTD = 8411' TO HV -9 Actual schematic 6-20-2007 Updated by: JGE 50-231-20027-00 CC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT -THF: 16.4' Tbg lift threads - 31/2" IBT Tree cxn - 3" Bowen cxn Well Name: Field: PROPOSED SCHEMATIC State: Production Tubing: 3N', 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection sidepocket mandrel at 2495' (Macro SFO1-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' Junk/Fill: -Tag fill @ 8327' on 1/31/05 max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' an out on T-5 (12/15/04) as soon as fluid hit perfs T-5 Sand (7440'- 7500' gross) was frac ated on 12/18/04 with 99,700 lbs of Ottawa Sand in BJ Lightning -2000 gel. B120 B135 T-16 Happy Valley #9 Deep Creek Unit Alaska Conductor: 13W. 72 ppf, L-80 to 73' Surface Casino: 7", 26 ppf, L-80, BTC -Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top -jobs (51 bbl and 4 bbl) 120: ±6,885'-±6,915'(±30' Proposed) 135: ±7,140'-±7,154'(±14' Proposed) -IB: ±7,251'-±7,257'(±6' Proposed) -5: 7448'- 7469'(6 spf, 12/17/04) (Re -ped -5: 7440'- 7470'(6 spf, 1119/05) -5: 7490'- 7500'(6 spf, 11/8/04) -7: 7680'- 7700'(6 spf, 11/8/04) -8: 7760'- 7786'(6 spf, 11/8/04) -10: 7837'- 7867'(6 spf, 11/8/04) -17: 8218'- 8237'(6 spf, 11/5/04) HV -9 Proposed Schematic 01-29-19 Updated by: DMA Production Liner: 31/2", 9.2 ppf, L-80, IBT-Mod J liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' PBTD = 8411' with 189 bbl of 12.0 ppg Litecrete FCemented TD HV -9 Proposed Schematic 01-29-19 Updated by: DMA zDs1-- ief �7 Davies, Stephen F (DOA) From: Anthony McConkey <amcconkey@hilcorp.com> Sent: Monday, February 4, 2019 12:53 PM To: Davies, Stephen F (DOA) Cc: Ted Kramer; Taylor Childers Subject: RE: [EXTERNAL) Happy Valley A-09 (PTD 204-170; Sundry 319-044) - Question Hi Steve, Both Ted and Taylor are on vacation, so 1 figured I could step in and help with the question. Regarding the rule specified under CO 553A — the perforation requests for both HVA -09 & HVB-12 are compliant. Both wells are well over 1500' from the Deep Creek Unit external boundary in each requested interval. The map below shows the distances from the boundary (Red lines are the external unit boundary, blue lines indicate the current PA). The green circles around the two wells in each map show a 10 -acre radius. As you can see, the distances between the wells are well over the 10 acre minimum spacing. I've attached the BEL50, BEI -135, & TY18 maps. Taylor Childers (Geo for Happy Valley) is on vacation, so I don't have a map specific to the BEL 120 at my disposal. However, I believe the distances seen within BEL50 & BEL135 should provide sufficient evidence that the spacing is adequate within the BEL120. Please let me know if you have any other questions, Thanks! Anthony McConkey Reservoir Engineer Kenai Asset Team, Hilcorp Alaska 3800 Centerpoint Dr., Anchorage, AK 99503 (w) 907-777-8460 (c) 907-529-6199 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, February 4, 2019 10:25 AM To: Ted Kramer Subject: Happy Valley A-09 (PTD 204-170; Sundry 319-044) - Question Ted, I'm reviewing Hilcorp's application to perforate Happy Valley A-09. I see that Item 2d of Hilcorp's proposed E -Line Procedure states: "Spacing allowance is based on CO 553A, no restrictions in Beluga Gas POOL" CO 553A, Rule 2, Well Spacing, actually reads: "Spacing units shall be a minimum of 10 acres. The Happy Valley Beluga/Tyonek Gas Pool shall not be opened in any well closer than 1,500' to the external boundary of the Deep Creek Unit." Will Hilcorp's proposed perforations in the BEL 120, BEL 135 and T-18 sands within A-09 conform to the spacing requirements of CO 553A, Rule 2? Thanks, 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 eov. 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -2000 Jan -2005 Jan -2010 Jan -2015 ., Produced Gas (MCFM) o GOR Produced Water (BOPM) C Produced Oil (BOPM) HILCORP ALASKA LLC, HAPPY VALLEY A-09 (204-170) DEEP CK, HV BELUGA/TYONEK GAS Monthly Production Rates 10,000,000 1,000,000 100,000 10,000 1,000 100 10 1 Jan -2020 SPREADSHEET_Prod-Inject_Curves_Well_V117_2041700_Ha ppy_Valley_A-09_20190204.xlSx 2/4/2019 ) D{L.c-- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041700 Well Name/No. HAPPY VALLEY A-9 Operator UNION OIL CO OF CALIFORNIA API No. 50-231-20027-00-00 MD 8478 TVD 6999 Completion Date 11/5/2004 Completion Status 1-GAS Current Status 1-GAS UIC N -~~--~.~~- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes "~-----_..__..__._-- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments r Pds/ð/"r,V12889 Cement Evaluation 1 2900 8391 12/7/2004 SLIM CEMENT MAPPING I w: (A.) S~1 TOOL 12889 Cement Evaluation 5 2900 8391 12/7/2004 SLIM CEMENT MAPPING ~ TOOL i ! C Pds 12890 Perforation 1 7440 7837 12/7/2004 PERFORATION RECORD f S~1 2.5" HSD 2506 PJ 6SPF 12890 Perforation 5 7440 7837 12/7/2004 PERFORATION RECORD 2.5" HSD 2506 PJ 6SPF ! C PdS//:JI.1t;(12891 I nd uction/Resistivity 0 8468 Open 12/7/2004 ARRAY {.... I'\- S INDUCTIONITHREE- LlTHO- DENSITY/COMPENSA TED NEUTRON/SHe SONIC ~ 12891 Induction/Resistivity 2 sM'" 0 8468 Open 12/7/2004 ARRAY INDUCTIONITHREE- LlTHO- DENSITY/COMPENSATED NEUTRON/SHe SONIC TVD 12891 I nd uction/Resistivity 2 sfIV" 1 0 8468 Open 12/7/2004 ARRAY INDUCTIONITHREE- LlTHO- DENSITY/COMPENSATED NEUTRON/SHe SONIC/*PLA TFORM EXPRESS fII D 12892 Completion 7390 8362 12/712004 COMPLETION RECORD s! 2.5" HSD POWERJETS 12892 Completion 5 7390 8362 12/7/2004 COMPLETION RECORD 2.5" HSD POWERJETS . . DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041700 Well Name/No. HAPPY VALLEY A-9 Operator UNION OIL CO OF CALIFORNIA API No. 50-231-20027-00-00 MD 8478 TVD 6999 Completion Date 11/5/2004 Completion Status 1-GAS Current Status 1-GAS UIC N /' ~ C Pds 12893 Cement Evaluation 0 3006 12/7/2004 SLIM CEMENT-MAPPINGI I ~ TOOL I ¿1 I 12893 Cement Evaluation 5 0 3006 12/7/2004 SLIM CEMENT MAPPING I TOOL ./ Mud Log 2 Sep 57 8478 Open 12/6/2004 ~ Report: Final Well R 0 0 12/6/2004 Epoch Final Well Report w/CD 4 Mud Log .x )... 2 Col 57 8478 /VI l) o.-....J .,.. f/ D . t: ~e Notes 2 Col 57 8478 Epoch Drilling Dynamics Log {V'ó V C Pds 13264 Completion 6390 7650 Case 7/29/2005 Completion Report Halliburton Fasdrill Bridge B~1 Plug 13264 Completion 5 6390 7650 Case 7/29/2005 Completion Report Halliburton Fasdrill Bridge Plug C Dlsl PbSJ 3265 Perforation 6300 7500 Case 7/29/2005 Perforation Record 2.5 Power Jets 6 SPF ~ 13265 Perforation 5 ~ 6300 7500 Case 7/29/2005 Perforation Record 2.5 Power Jets 6 SPF Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . ADDITIONAL INFORMATION W Well Cored? Y~ Daily History Received? Chips Received? ~y I rr Formation Tops (Ð>N Analysis ~ Received? -_.~-- Comments: DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2041700 Well Name/No. HAPPY VALLEY A-9 Operator UNION OIL CO OF CALIFORNIA MD 8478 TVD 6999 ~ ~'et;'_ n Date 11/5/2004 Compliance Reviewed By: Completion Status 1-GAS Current Status 1-GAS UIC N Date: :2. a Ar+2L-~ ~ API No. 50-231-20027-00-00 . . ,·/-'11·,·1,' ¡. , u~ . ! ¡ I ¡ I ;' l / ; ! ! j / FRANK H. MURKOWSKI. GOVERNOR . . ALASIill OIL AND GAS CONSERVATION COMMISSION November 9,2005 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Larry Greenstein UNOCAL [Chevron] P.O, Box 196247 Anchorage, Alaska 99519 \.f--Of} J.fJ. Ot ~/-\ Dear Mr. Greenstein: The Alaska Oil and Gas Conservation Commission ("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 t10w at the wellhead. An SVS component failure rate of 30 percent was identitìed during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a íàilure 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 of performance 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 mlìSt 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, ~- \ , '""7").~ ",-ftvt% D' K é¿'7""l James B. Regg Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors Safety Valve & Well Pressures Test Repoli Reviewed ßy; 1'.1. Suprv Comm , Pad: DC_HAPPY_VALLEY_A Insp Dt 1111/2005 Inspected by Lou Grimaldi Interval 90 Days InspNo svsLG05 I 102044246 Related Insp: Field Name DEEP CREEK Operator UNION OIL CO OF CALIFORNIA Operator Rep Steele/Tresler Reason 180-Day Src: Inspector Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code A-I -I - -2030720 'f800 ¡ 600'--650~j p' I I;-T :.120 }~ ~~~;:~~~ ~ ':~'-j-¿~~ "~-~5~ ~ -·t Ç-T A-8 'I 204'1 î¿o'l-¡¡oõ- 6ÛU' - 600 - P ['6 j. "I}.-y .:_L~~.L7~~_ï8~~ ~~~ _ 5~O P _ .~.._, DateSI Oil, W AG,GlNJ, Inner Outer Tubing GAS,CYCLE, SJ PSI PSI PSI Yes/No Ycs/No --'~ .-r--¡ - -l I-GAS 0 0 950 No No ----- ~---- ----- --~- - - -- 1 I-GAS 0 0 900 No No I ---~~ -- -- - ,- I'" . - ~ ~ I-GAS 0 0 805 No NOj -- -- - - I-GAS 30 0 820 No No ----. I-GAS 0 0 795 N9,__ L_ No -~-- ---- --- -- --- Commcnts Performance r-w~li;- Components 1__- "-------_..""--- wells 2,8,&9 failed to close, appeared 10 be froze Pad manned and wells observed, heaters will be applied and valves thawed and successfully retested by 12:00 ] 1/02/05 or be shul-in Outstanding equipment setup and appearance of maintenance. Failures Failure Rate .JQ._. ___ _.:3._ _,_"._lQ'YQ._ --~- - --'- .... --.- ._-_..._--.--~---- ._._~- . Wednesday, November 02, 2005 . 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 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 Date: July 27,2005 PERFORATION RECORD 2 HSD POWERJET GUNS ·so¿ài¿oo¿soo . . HAppy VALLEy:io ·PERFORATIONmm RECORD 2 HSD ............... ...........m P0'NEflJET GUNS 502312002800 HAPPYVALLEY-10 MULTIPLE PROPAGATION RESISTIVITY ...mm .............. GAMMA RAY MD 502312002800 HAPPY V ALLEY-10 MULTIPLE PROPAGATION RESISTIVITY GAMMA RAY ND 502312002900 HAPPY VALLEY ·11 : GAMMA RAY I ëci COMPLETION RECORD 2.5 HSD POWERJETS 502312002900 HAPPY VALLEY -11 COMPLETION 5 INCH RECORD 2.5 HSD POWERJETS 502312002900 HAPPY VALLEY-11 é COMPLETION 5 INCH RECORD 2.5 HSD POWERJETS 502312002900 ... HAPPYVAíIÊy:i1nCOMPLÊTION .. 5iNCH RECORD 2.5 HSD POWERJETS 502312002900 HAPPY VALLÊy:i1cOMPLETION 5 INCH RECORD 2.5 HSD POWERJETS 6 SPF, 60 DEGREE PHAZED 502312001/;00 HÀPPyvALLÊy:jm COMPLETION 5 INCH RECORD WEATHERFORD nm. ...m ...... . WRP PLUG 502312002300 HAPPY VALLEY·8COMPLETION .. 5 INCH RECORD 2.5 HSD POWERJETS 6 SPF 502312002300 HAPPY VALLÊY'-S . . COMPLÊTíOJÍi· 5 INCH RECORD HALLIBURTON FASDRILL BRIDGE ..PLUG Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. 204-186 204·186 204·186 204-207 204·207 204-207 204-207 204-207 203·222 204·114 204-114 U Ö}JJ Received By: pds 215 INCH 11·0ct-04 3860-8420 215 INCH 11·0ct-04 3860·8420 5 INCH 30-Nov·04 7000-10003 o las, metafile, viewer o ...................,..---,-.--.......--.,..... las. metafile, viewer pds pds 03·Dec-04 9530-9654 04·Dec·04 pds 9104-9154 01-Dec-04 pds 9262-9636 10-Dec-04 9260-9640 pds 19-Apr-04 ,_·____,·._·____.,,·'_'.'.·m.·.·._.".·.. 10270·10545 o . 09·Mar-05 1 pds 3900·8440 09-Dec-04 ,. ··,·____~·~___·_·_'·,···,·ù·.,·^~',·,',,·,·, 4020-5630 pds I Date / J-.. M-~ ,- 204-170 502312002700 204-170 '^'., ·.wow.·.·_w.·.·_·_·._·...·_____·_·... w""""',-.W" 501231200270 o . HAPPY VALLEY-9 COMPLETION RECORD 2.5 HSD POWERJETS 6 SPF HAPPY VALLEy:g ;COMPLEiiÑ6 . ......... RECORD HALLIBURTON FASDRILL BRIDGE PLUG 5 INCH ·5INCH 18-Dec-04 09-Dec·04 6300·7500 6390·7650 . dlis.fma.pds ...- .. .............. J 3> ..?:. ~.~. pds f / 32 ~ '--l Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received By: I Date' . STATE OF ALASKA . Al.A! Oil AND GAS CONSERVATION COM.. ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool 0 Perforate 0 4. Current Well Class: Development [] Stratigraphic 0 RECEIVED MA Stimulate ,¡ Other WaiverD Til4~ikl~ Re-enter Suspended Well 5. Permit to Drill N ExploratoryD 204-170 Service 0 6. API Number: 50-231-20027 9. Well Name and Number: HVA-09 10. Field/Pool(s): Deep Creek Unit 7. KB Elevation (ft): 733' AMSL 8. Property Designation: Happy Valley 11. Present Well Condition Summary: Total Depth measured 8,478 feet true vertical 6,999 feet Effective Depth measured 8,411 feet true vertical 6,936 feet Casing Length Size Structural Conductor 73' 13-3/8" Surface 3,297' 7" Intermediate Production Liner 5,405' 3-1/2" Plugs (measured) n/a Junk (measured) n/a MD rvD Burst Collapse 73' 73' n/a n/a 3,297' 2,584' 7240 psi 5410 psi 8,476' 6,997' 10,160 psi 10,530 psi Perforation depth: Measured depth: 7,440 - 8,237' True Vertical depth: 6,029 - 6,771' Tubing: (size, grade, and measured depth) 3-1/2" L-80 3,083' Packers and SSSV (type and measured depth) Baker ZXP liner top packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Frac stimulated T-5 sand (7,440 - 7,500' gross) on 12/18/04 with 99,700 of 20/40 sand in 20# borate gel. ISIP = 2342 psi. Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 400 0 900 2,000 0 900 15. Well Class after proposed work: Exploratory Development ,¡ 16. Well Status after proposed work: OilD Gas [] WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl n/a n/a Tubing Pressure 750 750 13. Service x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 304-483 Contact Gary Eller 263-7848 Title Drilling Manager Signature Phone 907-276-7600 Date 3/11/2005 RBDMS BfL MAd I. d 2005 ORIGlr~AL CONFIDENTIAL RBDMS BFL Mil, ¡ . lDD~ Form 10-404 Revised 04/2004 Submit Original Only . API: 50-231-20027 AOGCC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3%" IBT Tree cxn - 3" Bowen cxn Production Tubina: 3%", 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection sidepocket mandrel at 2495' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" 00 seals - Muleshoe at 3083' Stimulation: The T-5 Sand (7440' - 7500' gross) was frac stimulated on 12/18/04 with 99,700 Ibs of 20/40 Ottawa Sand in BJ Lightning-2000 gel. Junk/Fill: - Coil cleaned out to 8323' on 12/20/04 Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' HV-9 Actual schematic 1-19-2005 · · · · · · · · · · · · · · · ... . Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13%",72 ppf, L-80 to 73' Surface Casina: 7", 26 ppf, L-80, BTC-Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Open Perfs: T-5: 7440' -7470' (6 spf, 11/8 & 12/17/04) T-5: 7490' - 7500' (6 spf, 11/8/04) T-7: 7680' - 7700' (6 spf, 11/8/04) T-8: 7760' - 7786' (6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11/8/04) T-17: 8218' - 8237' (6 spf, 11/5/04) Production Liner: 3%", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete CONFIDENTIAL Updated by: JGE , , 12/9/04 . . MIRU Schlumberger. Conduct PJSM. Decided to shut down until we could get a gauge ring available to RIH prior to running bridge plug. RD e-line. Move to HV-8 while waiting for gauge ring from town. RU Schlumberger again. Conduct PJSM. Pressure test lubricator to 2500 psi using methanol. PU and RIH with 2.80" gauge ruing down to 7650'. Well has 2000 psi on it so slow going. No problem going through perfs 7440' - 7500'. POOH. PU Halliburton Fasdrill bridge plug (OD = 2.69"). Tie into SCMT log of 11/1/04. Set plug at 7595', good indication of setting. Picked up then went back down and tagged plug. POOH. 12/1 0/04 Finished rigging up Rain for rent tanks, United Rental delivered and hooked up glycol heater to tanks, Set portable generator next to heater and tied in. WBI brought 25 pallets Baroid jell. Finish snow and pad cleaning. Received last load of sand for BJ. 12/11/04 Continue to fill Rain for rent tanks with water, plow snow from location. Plow and sand road. BJ and WBI hauled in BJ equipment. We took precautions on Oil Road by staging a pickup at the top of Dolly Cr. hill to control any traffic coming from the caribou hill side. Held PJM and orientation Drilling/Production with BJ. BJ started rigging up equipment and loading sand. 12/12/04 Snowing and blowing this morning had crews plowing from highway into location. Cleaned snow from pad. BJ finished hauling in and spotting equipment. BJ finished unloading sand. Used all safety precautions on moving equipment in on Oilwell road. 12/13/04 Bad snow last night through today really slowed down all operations. Called grader and truck out early am had to plow most of the day to keep up with it, snowed good 10 or more inches. BJ spotted equipment broke sacks of gel put into water tanks. Generator down 5 hours Peak repaired. Glycol heater went down United responded and repaired. 12/14/04 PJSM with BJ & Peak (stressed all personnel will use ice cleats) BJ finished spotting equipment and equipment and heaters, ran hard line from unit to HV-A08, spotted tanks. Steam on wheels preheated water tanks. PTS delivered iron basket and sand buster. Finished clearing snow from location. Peak brought out supersucker. All lines and equipment spotted to frac this well after HV-A08 12/15/04 Produce well to sales. Close both master valves to isolate well. ND flow tee, NU flow cross. RU BJ frac iron onto well HV-9 from HV-8. Pressure test lines to 6300 psi, including newly installed flow cross. Closed flowline valves. Casing pressure = 1027 psi. Make repairs to BJ frac pump and chem-add communications that were problematic during HV-8 frac. Open well up, SITP = 940 psi. Bullhead 45 bbl of 6% KCI + additives at 8 bpm to load hole. Shut down briefly, then resuming pumping 6% KCI at 14.3 bpm with 4870 psi TP. Pump 40 bbl of KCI, then shut down for minifrac. ISIP = 1612 psi. During shut-down, blend gel in pre-hydration tank. Begin pumping BJ Lightning 2000 pad at 17.5 bpm with approximately 4000 psi TP. When the leading edge of gelled fluid hit the perfs the well locked up completely. Reach maximum pressure of 5500 psi, but unable to pump in at all. Attempt flowback of well followed by pump-in without any success. Repeat process several times with no improvement. Call office to discuss options and forward plan. RD BJ frac iron from HV-9. Suck out frac lines to shut-down for night. Transfer gelled fluid to frac tank #5. Begin refilling frac tanks #3 and #4 with fresh water. Steam-on-Wheels maintaining temperature on tanks #1 and #2, and begin heating fluid in tank #3. Transfer used fluid from catch tank to G&I tanks. 12/16/04 HV-09 (AFE 163398) morning report summary, CONFIDENTIAL: last revised 3/11/2005, Page 1. CONFIDENTIAL · . SDFN, waiting on BJ coil tubing unit to arrive. Refill frac tanks #3 and #4 with fresh water, and Steam-on-Wheels heated tank #3 up to 70 deg F. BJ frac crew cleared sand out of their blender, then used blender to mix KCI in tanks #3 and #4. Tank #3 contains 6% KCI for frac fluid, tank #4 contains 3% KCI for coil tubing clean out. BJ coil unit arrives on location, had crew go through site orientation. RU 1.75" coil tubing unit on well HV-9. RU to pump fluids from tanks #4 and #5, and take returns to Johnson tank. Conduct PJSM. Pump pig through coil tubing reel using 50/50 methanol blend. Retrieve pig from reel. 12/17/04 Displace methanol in reel with KCI fluid. Break down, install coil connector, MHA, and reverse-jet wash tool. Pressure test BOPE and flowback line to 300/3000 psi using 3% KCI. RIH with coil tubing to 6700' at 80 fpm while circulating at minimum rate. When reach 6700' pump 15-bbl pill of slickwater and wash in hole at 30 fpm. Tag bridge plug at 7595'. Increase rate to 2 bpm, circulate bottoms up. Shut down pump, drop 3/8" ball to open up-jets in BJ reverse-jet wash nozzle. After ball reached bottom, reduce rate to 1.5 bpm and POOH at 60 fpm. Pump 15 bbl pill of slick water at 2700', continue circulating OOH. Shut in well. Displace KCI in reel with methanol, then purge reel with nitrogen. RDMO BJ coil tubing. NU Bowen tree connection. MIRU Schlumberger electric line. Conduct PJSM and pressure test BOPE to 2000 psi. PU 20' of 2-1/2",6 spf hollow carrier guns loaded with PJ2506 charges. Guns are equipped with SECURE firing heads. RIH, tie in with CCL to GR/CCL log of 9/1/04. Reperfthe T-5 Sand 7448' -7468'. POOH, all guns fired. RDMO Schlumberger. Steam on Wheels reheating frac tanks #1, #2, and #3 to 70+ deg F for frac tomorrow morning. 12/18/04 Continue heating Rain-for-Rent frac tanks using Steam-on-Wheels. BJ frac crew arrives, RU on HV-9 to perform frac stimulation. Conduct PJSM. Blend gel in pre-hydration unit. Pressure test frac line to 6300 psi using KCI water. Casing pressure = 930 psi. Open well up, SITP = 0 psi. Bullhead 29 bbl of 6% KCI + additives. Able to break down perfs and inject, but treating pressure is 4950 psi at 13 bpm which is significantly higher than previous injection on 12/15/04. Switch to gel on the fly, begin pumping 130 bbl of pad using Lightning 2000 gel system + additives at 15.1 bpm with 4520 psi TP. Extended the volume of pad by 11 bbl due to high treating pressure. Pumped 99,700 Ibs of 20/40 Ottawa Sand + Flexsand MSE staged from 2 to 8 ppa in 516 bbl of BJ Lightning 2000 frac gel. Saw a significant spike in treating pressure when 2 ppa sand hit the perfs, so extended length of 2 ppa stage. The perfs cleaned up shortly afterward and improved with continued pumping. Placed 100% of design. Average treating pressure was 3200 psi at 14.8 bpm. Proppant was tagged with Ir-192 in 2-6 ppa stage and Sc- 46 in 8 ppa proppant stages using Zerowash radioactive tracer. Tagged gelled fluids with SpectraChem chemical tracer. Displaced with 70 bbl of KCI. ISIP = 2342 psi, 5-minute = 261 psi. Load to recover = 785 bbl from today's frac plus 170 bbl from the attempt of 12/15/04. Secure well. RDMO BJ all frac equipment. Clean up pad. Pick up used liner. Consolidate 6% KCI fluid in frac tanks. Clean out frac sand and fluids from coil tank. NU tree cap. Pump methanol into tree to freeze protect. 12/19/04 Lay 50' x 100' liner. MIRU 1-3/4" coil tubing unit. Stab pipe, NU BOPE. Move SSV and flowline from HV-8 to HV- 9. RU PTS' sand buster and flowline. SDFN 12/20/04 PJSM. MU coil connector, perform pull test.15,000# PJSM, Load Coil Tbg. Choke lines pumped through choke(ice plug) to Johnson tank W/ 50/50 Methanol. Test lubricator, BOPE, and flowline to test separator 300/3,000psi Displace 50/50 with 3% KCL Pull off injector head and lubricator Make up 2-1/8 Mtr. & Mill 2.80 Pressure test Riser. Tie Down injector head Open up Well 25psi. RIH checking weights going in hole. Pumped @.25bpm Increased T/.75 bpm @ 7,000'. Tagged Plug @ 7,590' Increase Pump rate T/ 1.2 bpm (50.4gpm). Milling plug 7,587' -7,590'. Took 1 hr to mill through plug. Wash to 8,323 tagged and stalled. P/U Pump 30 bbls Drop Ball, Shift Circ. Sub Start Nitrogen Displacement Maintaining Neutral at top perfs. 40bbls returned Pooh. Shut well in with 2, 185psi on well. Bleed nitrogen off and pump Methanol in Coil. Rig Down B.J. Coil Tbg. To move over to HV A08 12/21/04 HV-09 (AFE 163398) morning report summary, CONFIDENTIAL: last revised 3/11/2005, Page 2. CONFIDENTM .! , PJSM.' Prep to flow well to test. . well to flow. SITP = 2080 psi. Small flaree pressure had bled down to 200 psi. Shut in, wait to build pressure. Tubing pressure quickly built to 525psi.@ 05;00 then stalled remained the same. Clean out berm area and check all of liner for tear or rips & holes. Rig up to HV-9, MU tools and riser, NU BOPE, stab injector head. Vetco re-grease all valves on tree. Wait on nitrogen unit to arrive. Open up well to choke to make sure line is clear. Nitrogen arrived. Test BOPE to 300/3000 psi using KCI water. Purge lines with nitrogen. Conduct PJSM and operations meeting. PJSM on proposed nitrogen pump schedule and procedure for job. 12/22/04 Strap Tanks, open well 435 psi. @ 00;23hrs. RIH start Nitrogen at 450 scfm @ 500', Fluid in returns @ 00;43hrs. 1043'. Raised Nitrogen Rate @ 4,950, continue in hole to 8300'. Total fluid returns @ 03;52 110 bbls. Still making about 30 bbl/hr. No sign of sand or solid through perfs or fill. Continue lifting with nitrogen while POOH, used 233 mscf total. Pull out of hole get above top perfs and increase to 1,000 scfm, Ran out of nitrogen at 4200'. Total return of fluid 120 bbls but well still producing. Pull up into BOP, shut swab valve well continue to flow 300 psi at choke. Adjust to hold 100psi back press. Turn over to testers. Flow Well Back. BJ rigging down from HV-A09 to move to HV-A08. Peak picks up and move liner to HV-A08 clean up location. Haul fluid from HV "A" pad to NNA for injection. 12/23/04 Flow back well. Build berm for tanks we are using to drill out with, Empty tanks unhook and put in berm Hook heater back up and fill tank back up W/drilling fluid, Clean up location and empty ditches and clean out tanks, "Well data @ 08;00 Rate 1.236 mmcfd. Total water back 272 bbls @ 23.00 Rate 1,467 mmcfd. Total water back 291 bbls Increased Back press on well 127 - 138 psi. 12/24/04 Started pinching back on back press 03:00 Rate 1.521 mmcfd Total water back 295.9 bbls Increased Back press on well. Let build back to 1 ,404.mcfd Total bbls Recovered 301.6 no water increase since 06;00am Open well to production Close well to test, Well on production to test separator @ 18:26hrs. 1.4 mmcfd. 12/25-28/04 Well production 1.5 mmcfd. Caught up on the split cost for HV-A09 & HV-A08. 1/31/05 No activity. Well producing to test separator at 1717 mcfd and 9 bwpd with 720 psi FTP. MIRU slickline. Conduct PJSM. Swab valve froze. Get heater to thaw out swab valve. Pressure test lubricator. RIH with 2.5" gauge ring. Tag 8327' MD. POOH. PU Protechnics memory production logging tools and RIH with the well flowing. Make up and down passes at 30,60, and 90 feet per minute across 7000' to 8300'. POOH. Download log data. Data good. RD slickline. SDFN 2/1/05 RU slickline. PU and RIH with Protechnics multi-isotope tracer log. Log at 30 fpm across frac interval from 6400' - 8300'. POOH. Download log data. RD slickline, move to HV-8. Well producing 1711 mcfd with 693 psi FTP. CP = o psi. HV-09 (AFE 163398) morning report summary, CONFIDENTIAL: last revised 3/11/2005, Page 3. CONFIDENTfft r STATE OF ALASKA ALASelL AND GAS CONSERVATION COMMI~N",.. '~"r"'" WELL COMPLETION OR RECOMPLETION R~ORT AND L~tð: 1 a. Well Status: OilD Gas0 Plugged U Abandoned U Suspended U WAGU 1 b. Well Class: ¡ i\ \iJa ft n': Q 20AAC 25,105 20AAC 25.110 Development 0 ~ÞM t6fve.JL GINJD WINJD WDSPL D No. of Completions 1 Other Service D ;\·~~tr~ti~íjlp\:IiYT~SlO - .. '. 0_'."" _..... . 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number:' Union Oil Company of California Aband.: 11/5/04 204-170 2 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519-6247 September 13, 2004 50-231-20027-00-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1,104', FSL, 1,300' FEL, Sec. 22, T2S, R13W, SM September 22, 2004 HV-A09 Top of Productive Horizon: 8. KB Elevation (ft): 15. Field/Pool(s): 799 FSL 2 FEL Sec. 21, T2S, R13W, SM 733' Total Depth: 9. Plug Back Depth(MD+ TVD): Deep Creek UniUBeluga 368 FEL 764 FSL Sec. 21, T2S, R13W, SM 8,411 '/6,936' 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: X = 227,963 Y = 2,189,649 8,478'/6,999' C-061590 (surface) C-061589 (TO) TPI: X = 223,987, Y = 2,189,405 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: X = 223,621, Y = 2,189,379 n/a n/a 18. Directional Survey: Yes o No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost: feet MSL n/a 21. Logs Run: GRlCCL, AIT, SCMT, PEXlDSI 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 13-3/8" 72# L-80 0 73' 0 73' Driven See Schematic for cement detail. 7" 26# L-80 0 3,297' 0 2,584' 8-1/2" 3-1/2'" 9.2# L-80 3,071' 8476' 2,436' 6,997' 6-1/8" 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 3,083' 3,046' T-5: 7440' - 7470' (6 spf, 11/8/04) T-5: 7490' - 7500' (6 spf, 11/8/04) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. T-7 7680' - 7700' (6 spf, 11/8/04) DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED T-8 7760' - 7786' (6 spf, 11/8/04) T-10: 7837' -7867' (6 spf, 11/8/04) T-17: 8218' - 8237' (6 spf, 11/5/04) 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): November 12,2004 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: /GaS-Oil Ratio: 11/15/2004 1/9/1900 Test Period ",0 281 0 open Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 770 0 24-Hour Rate ..... 0 750 0 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". '1"..."...'....",.....->.....,........,...'.""...-'«... RBDMS 8Ft JAN 3 1 :. none 7005 .~ n" i L~EU .! ()RIGlri~~\L rnNFfOFNTJAl r ~ ij;;~",+."",-'W",!,....,-~,-, ~. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE G 28. 29. FORMATION TESTS NAME TVD Include and briefly s ize test results. List intervals tested, and attach Beluga 2:10 2,234 detailed supporting déo. necessary. If no tests were conducted, state BLG-49 5,381 4,169 "None". MTL4 5,783 4,537 none MTL3 6,202 4,912 BLG-90 6,319 5,016 MTL2 6,470 5,151 MTL1 6,663 5,324 Tyonek 7,198 5,806 Tyonek 7,201 5,808 T1TOP 7,227 5,832 T 4A TOP 7,307 5,906 T5 TOP 7,445 6,033 T6 TOP 7,533 6,115 T7 TOP 7,669 6,241 T8 TOP 7,749 6,315 T10 TOP 7,836 6,395 T12 TOP 7,936 6,489 T17 TOP 8,198 6,734 T17 TOP 8,206 6,742 T19 TOP 8,402 6,927 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steven S. Lambe 263-7637 Signature: Title: Drilling Manager Phone: 907-276-7600 Date: 1/20/2005 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. 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". CONFIDENTIAL Form 1 0-407 Revised 12/2003 OR/Glf\IAL ;:~=~~::~;\V~~;~ire~ti~n~I~~~~Y~~.U~~! _ Report Name Well Date Created Position Log HV10 1/19/2005 Well Name CURRENT STATUS API KB Surf X Surf Y (ft) (ft) (ft) HV10 GAS 502312002800 733 227,968 2,189,662 MD rvD SSTVD X Off Y Off X Y (ft) (ft) (ft) (ft) (ft) eft) (ft) o 0 733 0 0 227,968 2,189,662 176 175 558 0 0 227,968 2,189,662 238 237 496 0 1 227,968 2,189,663 300 299 434 -1 2 227,967 2,189,664 Inconsistant Data 361 360 373 -3 3 227,965 2,189,665 Click tiER!; 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 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 Inc (deg) 0.0 0.6 0.7 Azimuth (deg) o 321 329 . CONFIDENTIAL 3,982 3,084 -2,352 -1,733 1,418 226,235 2~.80 . 4,077 3,152 -2,420 -1,785 1,460 226,183 2, 22 4,171 3,221 -2,489 -1,835 1,497 226,133 2,191,159 4,266 3,294 -2,562 -1,885 1,533 226,083 2,191,195 4,361 3,369 -2,637 -1,931 1,569 226,037 2,191,231 4,408 3,407 -2,675 -1,952 1,586 226,016 2,191,248 4,488 3,472 -2,740 -1,989 1,615 225,979 2,191,277 4,550 3,523 -2,791 -2,017 1,637 225,951 2,191,299 4,645 3,600 -2,868 -2,060 1,672 225,908 2,191,334 4,740 3,677 -2,945 -2,104 1,706 225,864 2,191,368 4,834 3,753 -3,021 -2,147 1,740 225,821 2,191,402 4,929 3,831 -3,099 -2,190 1,774 225,778 2,191,436 5,023 3,908 -3,176 -2,233 1,808 225,735 2,191,470 5,118 3,985 -3,253 -2,276 1,841 225,692 2,191,503 5,213 4,064 -3,332 -2,317 1,875 225,651 2,191,537 5,308 4,143 -3,411 -2,357 1,909 225,611 2,191,571 5,402 4,222 -3,490 -2,396 1,943 225,572 2,191,605 5,497 4,302 -3,570 -2,436 1,976225,532 2,191,638 5,592 4,381 -3,649 -2,475 2,009 225,493 2,191,671 5,686 4,461 -3,729 -2,514 2,042 225,454 2,191,704 5,781 4,541 -3,809 -2,553 2,074 225,415 2,191,736 5,876 4,621 -3,889 -2,592 2,107 225,376 2,191,769 5,971 4,702 -3,970 -2,630 2,139 225,338 2,191,801 6,065 4,782 -4,050 -2,668 2,170 225,300 2,191,832 . 6,160 4,864 -4,132 -2,706 2,200 225,262 2,191,862 6,255 4,946 -4,214 -2,744 2,229 225,224 2,191,891 6,349 5,028 -4,296 -2,780 2,258 225,188 2,191,920 6,444 5,110 -4,378 -2,816 2,288 225,152 2,191,950 6,539 5,194 -4,462 -2,852 2,316 225,116 2,191,978 6,634 5,277 -4,545 -2,888 2,344 225,080 2,192,006 6,760 5,389 -4,657 -2,934 2,380 225,034 2,192,042 6,886 5,502 -4,770 -2,979 2,414 224,989 2,192,076 7,013 5,616 -4,884 -3,022 2,448 224,946 2,192,110 7,139 5,730 -4,998 -3,063 2,482 224,905 2,192,144 7,266 5,846 -5,114 -3,104 2,513 224,864 2,192,175 7,392 5,962 -5,230 -3,143 2,544 224,825 2,192,206 7,518 6,079 -5,347 -3,180 2,575 224,788 2,192,237 7,645 6,197 -5,465 -3,216 2,604 224,752 2,192,266 7,771 6,315 -5,583 -3,251 2,632 224,717 2,192,294 7,865 6,403 -5,671 -3,276 2,653 224,692 2,192,315 7,960 6,492 -5,760 -3,300 2,673 224,668 2,192,335 8,086 6,611 -5,879 -3,332 2,700 224,636 2,192,362 8,212 6,731 -5,999 -3,362 2,725 224,606 2,192,387 8,362 6,874 -6,142 -3,397 2,756 224,571 2,192,418 8,420 6,929 -6,197 -3,410 2,767 224,558 2,192,429 CONFIDENTIAL . API: 50-231-20027 AOGCC: 204-170 1104' FSL, 1300' FEL Sec22, T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3Y2" IBT Treecxn - 3" Bowen cxn Production·Tubin<:J: 3V2', 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCI brine plus corroSion inhibitor Completion - Chemical injection sidepocket mandrel at 2495' (Macco SF01-CI) with 1/4", . 0.049" wall SS chemical injection line -·Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' Slickline tag fill at 8336' MD on 11/22/04 Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' HV -9 Actual schematic 11-22-2004 · · · · · · · · · · · · · · · ... . Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13%",72 ppf, L-80 to 73' Surface Casino: 7", 26 ppf, L-80, BTC-Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51 bbl and 4 bbl) Open Perfs: T-5: 7440' - 7470' (6 spf, 11/8/04) T-5: 7490' - 7500' (6 spf, 11/8/04) T-7: 7680' - 7700' (6 spf, 11/8/04) T-8: 7760' - 7786' (6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11/8/04) T-17: 8218' - 8237' (6 spf, 11/5/04) Production Liner: 3V2', 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' Baker ZXP packer, Ffexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete CONFIDENTIAl Updated by: JGE 9/10/04 . . MIRU on HV-09. Installed and tested Veto Gray Multibowl150 wellhead system on conductor pipe, tested to 1000 PSI 9/11/04 RU. NU stack less Hydril on wellhead. 9/12/04 RU 9/13/04 RU. Hook up turn buckles, hole fill, bleed off, drip pan and mouse hole. PU bales. Hang tongs. PU test joint. RU to test BOPs. Test BOPs 250/3500 for 4", 7". RD test equipment; install wear ring. Test mud line; Tighten swivel packing. Test OK. PU 4" HWDP; stand back. PU Spud BHA. Spud well and drill to 227'. Stand back 4" HWDP. PU MWD, flex collars. RIH, no fill. Drill from 227 to 758'. TPIG = 701 APIG = 127.5 9/14/04 Drill from 758 to 908. Circ hole POH to the MWD PU 5" HWDP and drill 908' to 1026'. At 1026' obseNed lost of returns, lost 26 bbls, reduce pump rate to 306 gpm, regained partial returns, SD pumps and establish static loss rate of 0 BPM, resumed pumping and staged pump rate up from 128 to 306 GPM with minimal losses, started adding LCM. Work pump rate up to 600 GPM. Drill 1026' to 1074' with minimal losses, lost returns completely at 1074'. POH to 774'. While mixing LCM pills, run back to bottom, pump pill, did not regain returns, POH to 774', Pump second pill established partial returns. Establish static loss rate 10 BPH, running short on surface volume. Build volume until 1080 barrels available. Resume directional drilling with 346 GPM, holding penetration rate to less than 150 FPH. Drill from 1074' to 1321'. At 1321' increase GPM to 375 and penetration rate to 200 fph, continue slowly working up GPM and penetration rate to 400 GPM and 275 FPH, midnight depth 1749'. Total losses for day 437 bbls. 9/15/04 Drill 8.5" OH to 3300'. Continue to loose mud @ 10-15 bph. Circulated and condition mud.; pump nut plug pill, did not see it either. Pump out of hole to top of 5". HWDP at midnight. Experience mud losses 25-30 BPH until getting to 1250' with bit. Lost approximately 75 bbls between 1300 and 1200'. At 700, the well began giving fluid back; 60 bbls during that connection; monitor well for 35 minutes, strapping pit. The well quit flowing back and quit taking fluid the rest of the way out of the hole. Note lost 225 bbls on trip out before regaining 60 bbls at 700' 9/16/04 LD 5" HWDP, jars and BHI tools. RU WOT to run casing. PU 7" 26# casing to 3270' filling pipe and topping off every 5 joints. Lost 142 bbls while RIH. Make up hangar, landing joint and circulating swedge, break circulation and wash down, land hangar in wellhead, circulate 2+ bottoms up. Break out swedge, RU cement head, circulate 7" casing while holding safety meeting. Test lines to 3000 psi, pump 22 bbls mud push; Cement 7" casing with 137 bbls, 12.8 lead slurry and 17 bbls of 15.8 tail slurry; drop plug, pump 5 bbls water and displace with 119 bbls of 9.0 mud. Bump plug with 1988 strokes, bring pressure up to 3000 psi and test casing for 30 min. Cement in place @ 2:30. Drain stack; install packoff. Check for flow after draining stack--- no flow. Test packoff to 3700 psi; total mud flowback totaled 45 bbls. Valves were closed on the 4" lines to the conductor. A gauge was installed and pressure built to 28 psi. PJSM on bull heading cement down backside. Pump 51 bbls of neat 15.8 ppg cement with2% CaCI. Initial pressure at .5 bpm was 75 psi; after pumping 5.5 bbls the pressure went to nothing at the wellhead then to a vacuum. A total of 51 bbls of cement was pumped; the lines were knocked loose and drained; the valves were opened to find the well on vacuum, the valves were closed. Monitor pressure- pressure built to 20 psi at 10:00 pm. Change rams from 7" to 4" and test BOPs. Had some problems getting blind ram test. Build new mud in the coil tank also. Peak hauling mud from pits to G and I for injection. PU wt on 7" on bottom at 3292'---95000; slack off wt---60000. HV-09 (163015) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 1. 9/17/04 . . Finish testing BOPs. RU and run Gyro to 3011 tagged up; Pumped 4.0 bbls with good cmt returns. RU lubricator to run Schlumberger CMTB log. RIH with e-line. Pressure up to 1500 psi and run CMTB log to surface from set down at 3017'. RD Slumberger e-line. Adjust Kelly hose. PU BHA; RIH with HWDP from the derrick to test MWD. PU drill pipe and stand back in the derrick; RIH PU singles to 3084'. 9/18/04 RIH one stand, attempt to screw into stand at 3084'. Break circulation, tag cement at 3240'. Choke drill, all hands operated choke. Blow down lines. Drill out cement, float equipment and 20 feet of new hole to 3320'. 70% formation in bottoms up sample RU Dowell to perform FIT, Dowell unit unable to pump against closed choke, had no problems circulating well through open choke, only able to get to a high of 144 psi in four attempts. RD Dowell; RU test pump, perform FIT, 14.19 MWE, RD test pump blow down lines. Drill 3320' to 3371 '; change over mud to KCL PHPA system. MWD not pulsing Attempt to get MWD working Circulate bottoms up, mix and pump. Dry job. POH. Change out MWD (Noted 4 small pieces gravel stuck in Pulsar sub) RIH with BHA, test MWD. RIH to 3274'. Fill pipe, test MWD. Drill 3371' to 3875 Having ART 4.1 hrs Pipe in ground 82.14 FPH AST 1.5 hrs ADT 5.6 hrs. 9/19/04 Directionally Drill 3875' to 4733'. Circulate bottoms up, monitor well POH to 4032' lots of overpulls, appear to be pulling through swollen clays, unable to pull past 4032' Back ream 4032' to 3845' POH 3845' to shoe at 3297', 30 - 40K overpull 4032' to 3825'. No overpull 3825' to shoe. NOTE: Ghost reamer depth was 3825' when trip was started Monitor well, pump dry job POH LD lead collar and 53/4" stabilizer, pick up 5 7/8" stabilizer, inspect bit. RIH, surface test MWD RIH to 4684. 9/20/04 Drill from 4733' to 5697'. CBU and monitor well; prep for short trip. Short trip to 4690' with the bit. RIH to 5697'. Straight pull with no overpulls to 5432. 20K - 40K overpulls 5432' to 5243'. Pump out of hole 5243' to 5204' with 15K - 30K overpulls. Pump and back ream out of hole 5204' to 4770'. Hole was progressively worse during trip out. Drill/slide from 5697' to 6011'. TPIG = 2711' for bit APIG = 63 fph. 9/21/04 Drill 6011' to 6643'. Pump sweep around. Short trip. POH to 5633' 30 -50K overpulls, 6350', 6190', 6170', 6024', 6003',5960',5787',5749'. Never had to pump or backream. RIH without any excess drag. Drill 6643' to 7415' 9/22/04 Drill 6 1/8" directional hole from 7415' to 7590'. Pump sweep around. Short wiper trip from 7590' to 6580'. No overpulls greater than 20K. RIH. No Excess drag. Drill 61/8" directional hole from 7590' to 8478' (Total Depth). Last 3 Connections were sticky. Pump nut plug sweep around and calculate strokes. Gauge hole calculated. POOH from short wiper trip. - Pump out from 8478' to 8190' and straight pull to 4116' (a few bobbles from 5230' to 4515' with Max O/pull of 25K, but mostly smooth hole.) Ghost reamer inside shoe. RIH to 6295' - Smooth. TPIG = 5173' f/ Bit APIG = 63.9 ftlhr. 9/23/04 Finish RIH with wiper trip - smooth. Safety Wash 25' to bottom @ 8478'. Pump sweep around (nut plug showed 3 bbls/over gauge). 506 units gas from wiper trip. Pump carbide pill around (showed 25 bbls/over gauge 11.7% wash out factor.) Monitor well. PuliS Stds. OK. Pump Dri-job. POOH. LDLD ghost reamer, stand back HWDP. LD Baker tools and bit. PJSM RU Schlumberger. Pick up tools. Load sources. RIH. Log open hole section. Run GR to surface, RD wireline. RU Weatherford tubing equipment, PJSM. RIH with 3 1/2" liner assembly to shoe @ 3297'. 9/24/04 HV-09 (163015) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 2. Brea~circulation @ shoe @ 3~Continue PU 3-1/2" Liner and RIH. PU ~eal bore ext, liner hanger, and ZXP Imer top packer assemblý'W RD WOTCO tongs. PU 6 joints 4" HWD~Õ jars, and RIH with HWDP and DP from Derrick to 8412'. Wash to bottom 8412' to 8478'.4' of fill circulate space out. MU cement head, circulate PJSM. Dowell pump 5 bbls CW 100, PT lines to 4000 psi, pump 15 bbls CW 100, using rig pump 30 bbls 12, ppg mud push, Dowell pump 189 bbls, 12 ppg cement, drop dart. Wash out lines, pump 5 bbls mix water. Dowell displace with 70.5 bbls 3% KCL, bump plug, pressure up to 3000 psi, (Hangar set) hold 3000 psi for 10 minutes, bleed off pressure 3/4 bbl back floats holding. Release from running tool with right hand rotation, PU to expose dogs, set packer by applying string weight. (CIP 11 :00 hrs). Test wellbore to 2000 psi for 5 minutes. Displace well over to 3% KCL water, mud push back as soon as displacement started, cement back 26 bbls into displacement. Circulate bottoms up. LD BOT cement head assembly service rig. POOH and LD DP. PU BOT polish assembly. RIH 32 stds and 1 single and tag 17' in on single polish PBR. Circulate and displace hole with clean 3% KCL. 9/25/04 Circulate and prep to LD 4" DP LD 97 joints 4" DP - LD BOT polish mill assembly. PU test joint and remove wear bushing. LD test joint RU WOTCO and Pollard. PJSM PU and RIH with 3 1/2" completion - 18 Joints - PU and MU chemical injection mandrel with 1/4" SS control line. Test and leave 1000 psi and hold and attach with SS banding sting into sealbore extension while pumping. Pressure up. Bleed off. Space out. Land and run in lock down pins. RU to pressure test. Pressure test tubing to 3500 psi for 30 Min - OK. Pressure test annulus to 1500 psi for 30 min - OK. Pull landing joint, Set BPV and RD WOTCO and Pollard. Change bottom rams to 7" Blow down choke lines and ready choke house for move. NO BOPE NU short tree with Vetco Gray. RR 11/1/04 Schlumberger MI/RU. Test lubricator to 2500 psi. with methanol. Run SCMT log under 1500 PSI per program. Tie in log: Schlumberger AIT Log Dated Sept, 232004. Top of cement @ 4092' 11/2/04 MI/RU Schlumberger CT. NU on HV-09. Prep for hydro test. 11/3/04 Make up wash nozzle and stab injection head. Test lines and BOP with KCL freeze protected fluid to (14 F) @ 4000 PSI. RIH and tag PBTD @ 8400' coil tubing measurements. Displace coil tubing and well bore with nitrogen. Recovered a total of 103 bbls in the Johnson tank, 73 bbl from the 3-1/2" tubing and 30 bbls from the 24 bbl coil volume 6 bbls extra from circulating to tank. POOH CT and leave 1350 psi nitrogen cap on well. RD. 11/4/04 RU flowline and SSV. Pressure test flowline. SDFN. 11/5/04 RU. Test lubricator with methanol to 3000 psi, good test. RIH with 20'· HSD WL DP 2.5" 2506 PJ, HMX 6-SPF. Tag bottom @ 8384' Wire line measurements. Tie into Schlumberger SCMT Log Dated Nov -01 -2004. 1500 psi under balance to formation. Perforate the T-17 Sand F/ 8218' - TO/ 8237' Shots fired @ 14:20 hrs. Started seeing a gradual increase in pressure as wireline was pulled out of hole. From 14:20 hrs -15:30 hrs pressure built from 1246 psi to 1419 psi. Open choke @ 15:35 hrs start taking down tubing pressure @ a 1.0 mm rate. Shut in well with 992 psi. Open choke and start taking down tubing pressure @ 1.0 MM rate. Shut in well with 600 psi on tubing. Open up well gas to flare @ 17:05 hrs. With a 590 psi flowing tubing pressure. Pinch choke to 11/64. (363 MSCFD) Stable flowing tubing pressure 541 psi @ 335 MSCFD. Continue flaring gas @ 2400 hrs. 11/8/04 RU PJSM. Make up and arm 30' x 2 1/5." 6 SPF, 60° phasing. Hollow carrier gun with PJ2506 Charges. Perforate the T-10 from 7837' to 7867' with well flowing 855 psi tubing pressure on 11/64 choke 540 MSCFD. All shots fired. Make up Gun # 2 RIH with 26' x 2 1/5" 6 SPF 60° phasing. Perforate the T-8 from 7760' to 7786'. With well flowing on 11/64 choke. Tubing pressure 862 psi, 538 MSCFD. Make up gun # 3. Perforate the T- 7 from 7680' to HV-09 (163015) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 3. 7700', with well flowing on 111eAoke, tubing pressure 867 Psi, 540 MSC~U gun # 4 10' x 2 1/2" 6 SPF 60° phasing. Perforate the T- 5 fro~90' to 7500', with well flowing on 11/64 ~Z: tubing pressure 870 psi, 540 MSCFD. POOH. Make up gun # 5 10' x 2 1/2" 6 SPF 600 phasing. RIH same. Tubing pressure.863 psi. Continue RIH, Tie in & perforate the T- 5 F/7440' - TO/7470' with well flowing on 11/64 choke 860 psi, 540 MSCFD Fired guns @ 00:35 hrs. POOH. LD gun all shots fired, 10' x 21/2",6 SPF 60° phasing. Tubing Pressure.858 psi. RD and monitor pressure build up & rate. (0500 HRS, 900 PSI, 562 mscfd) 11/9/04 Flow well HV-09 to test skid while flaring gas. Rate at midnight = 623 mcfd at 800 psi FTP. Pressure and rate still building. 11/10/04 Cost up date only SLB perf runs. 11/22/04 Producing well to sales at 951 mcfd, 0 bwpd with 771 psi FTP. MIRU slickline. Pressure test lubricator. RIH with 2.35" gauge ring. Tag fill at 8336' KB. POOH. PU tandem pressure gauges and RIH. RIH at 150 fpm down to 7100'. Log down from 7100' to 8316' at40 fpm. Make 5-minute stationary stop at 8316'. Log up to 7100' at 40 fpm, then POOH. Data good. RDMO slickline. HV-09 (163015) morning report summary, CONFIDENTIAL: last revised 1/19/2005 Page 4. . ~V~VŒ (ffi~ ~~~~[K\~ . c2ðf-f?o AI.A~IiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J. Gary Eller Completions Engineer Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Deep Creek BY -A09 Sundry Number: 304-483 Dear Mr. Eller: 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 fonn. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on liday or weekend. A person may not appeal a Commission decision to Superio Co unless rehearing has been requested. DATED this I~y of December, 2004 Encl. .. STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM~ON APP~ATION FOR SUNDRY APP~AL 20 AAC 25.280 \lJ6Æ fNS I llltl 2-004 1'4 11-/1--- ""' 1 Type of Request: Abandon U Suspend D Operational shutdown U Perforate U Waiver U Annular Dispos. U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory 0 204-170 ('" 3. Address: Stratigraphic 0 Service 0 6. API Number: PO Box 196247, Anchorage, AK 99519 50-231-20027 / 7. KB Elevation (ft): 9. Well Name and Number: 733' above MSL HV-A09 /' 8. Property Designation: 10. Field/Pools(s): Happy Valley Deep Creek Unit 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,478 6,999' 8,411' 6,936' 8,411 ' n/a Casing Length Size MD rvD Burst Collapse Structural Conductor 73' 13-3/8" 73' 73' n/a n/a .k' 8ur.f6eo 3,297' 7" 3,297' 2,584' 7240 psi 5410 psi 'St.(..vt.-c:£c..<.. Production Liner 5,405' 3-1/2" 8,476' 6,997' 10,160 psi 10,530 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,440 to 8,237' / 6,029 to 6,771' 3-1/2" L-80 3,083' /' Packers and SSSV Type: Packers and SSSV MD (ft): Baker ZXP Liner-top packer Baker lXP packer at 3,046' 12, Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 16-Dec-04 Oil 0 Gas 0 Plugged 0 Abandoned D 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Com m ission~epresentative: 17. I he~ ;~t the fOregOing~ true and correct to the best of my knowledge. Contact Gary Eller (263-7848) Printed N e J. Gary Eller c-' ~ Title Completions Engineer Signature -':x.~ '\.,.(\\\.... ~ ~ \..... Phone 907-276-7600 Date 12/10/2004 l '\ ~'.. ') COMMISSION USE ONLY \~ Jó t.1. ;~ ~~ Conditions of appro :JNotify Commission so that a representative may witness Sundry Number: , Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RECEIVED RBIDMS BFL DEC .2 () 2004 SCb"q~¡;j_ - 404 ' DEC 1 0 2004 Alaska 0;1 & Gas Cons. Commission App,," bf tf t;(L¡ RIG I N A L COMMISSIONER BY ORDER OF Anchorage ífí ~r THE COMMISSION Date: 1M () =We ~~ ' it in ~Plica:e F 10-403 . ed 12/2'tt.a~ INSTRUCTIONS ON REVERSE Sub . . Happy Valley #9 Deep Creek Unit Frac Stimulate Upper Tyonek Sand AFE 163398 '"' ! Well History: The Tyo ¡y/r -17, 10, 8, 7, and 5 Sands were perforated in early November. pr~tion from this well has continued to improve to 1300 mcfd /' with 755 psi FTP. Temperature surveys confirm that the T-5 Sand is contributing gas production at an estimated 200 mcfd rate. Obîective: Isolate and frac stimulate the T-5 Sand (7440' -7500') in well HV-9. 8l:lbsequefttly -;;illl::1:se øeil tttbil'ig to remø'.'@ tae bridg@ fJlug at 7881' that is WGA- isølatiHg prøàuetive Tyøftøk sanàs, eæà f)fe198fe the well fer 13føàw:etimu:e gtMes. Procedure: 1. Shut-in well HV -9. MIRU electric line. Pressure test lubricator to 2000 psi and conduct pre-job safety meeting. PU and RIH with 2.80" gauge ring to 7650', POOH. PU Halliburton Fasdrill bridge plug for 3Y2" casing and RI!J:: Tie in with CCL to SCMT log of 11/1/2004. Set Fasdrill bridge plug at 7595' MD. POOH, RDMO electric line. 2. Produce well HV -9 to sales while it is producing strictly from the open T -5 perfs. Record well test data. Production Operator should pressure up 7" casing to 1000 psi using methanol or diesel. 3. Shut-in well HV-9, close both master valves. ND the existing tee on the tree, NU and test a 3W', 6.5M flow cross instead. NU flowline spool and valves. Close the permanent wing valve and hydraulic SSV; flag both valves shut. RU 3W', 6.5M wing valve and pneumatic SSV on the opposite side of the flow cross. Have Vetco grease all the valves on the tree in preparation for frac stimulation, and after greasing avoid using the master valves at all (use swab and wing valves only). Move in five clean 500-bbl Rain-for-Rent frac tanks with manifolds and heating lines. Spot frac tanks as per BJ frac supervisor. Manifold tanks and fill with fresh water from the HV "A" pad water well using 2" hose. iliote: Frac tanks do not have to be lined and bermed as per memo of 11/16/2004 from Faye Sullivan.) Record fresh water usage on the daily log sheet provided by the Environmental Department. Use Steam-on-Wheels to keep tanks thawed, and prior to the frac stimulation heat each tank to 70° F. / 4. MI BJ Services Sand Kings and frac iron. Conduct prejob safety meeting. BJ will spot all frac pumps and blender on portable containment. Load one Sand King with 28,000 lbs of Flexsand MSE and the other Sand King with 195,000 lbs of 20/40 Ottawa proppant. RU BJ frac iron to well HV-9 and pressure test to J' 6500 psi. Maximum pump pressure during stimulation = 5500 psi. Install sensor HV -9 Frac Prog December 10, 2004 Happy Valley #9 Frac Stimulate Beluga Sand AFE 163398 Page 2 . . to monitor pressure on tubing annulus throughout the frac job. Verify that the wing valve and the SSV are both closed. RU Protechnics to pump radioactive and chemical tracer during frac stimulation. 5. Frac stimulate the T-5 Sand in well HV-9 following the stimulation of well HV-8. Frac HV -9 using the following schedule. Will plan to shut down briefly after loading the hole, then will shut down for 1 hour to monitor the mini-frac. We may cancel the minifrac if the weather is too ,/ cold for fear of freezing up the frac lines. Prior to the frac, Protechnics should perform a background radiation survey of the temporary flowback equipment and the permanent production and test separators. Following the frac, secure the well by closing the swab valve. RDMO BJ frac equipment. Do not attempt to flow the well back immediately. 6. Keep the HV -9 well shut-in until temporary flowback operations are completed in well HV-8. Do not close or function the master valves. 7. When HV-8 has finished flow testing, RU the PTS sand buster and the Unocal test skid on HV-9. Pressure test from the wing valve to the Unocalline heater to 4000 psi using methanol. Load the line heater with glycol. Spot the Johnson tank and the sand buster inside ofbermed containment having 110% capacity of the largest tank. 8. MIRU Schlumberger 1 %" coil tubing and nitrogen. Use KCl fluid in the Rain- for-Rent frac tanks for source fluid. Fluids will move from the 500-bbl tank via a/ transfer pump and dual pod filter into the blender unit into the coil tubing. Will take returns to a Johnson tank with a built-in gas buster. Second pod of blender unit will be used to mix HEC viscous pills as needed. Get a starting strap of fluids in the 500-bbl tank and the Johnson tank. Pressure test BOPE to 300/3000 /' HV -9 Frac Prog December 10, 2004 Happy Valley #9 Frac Stimulate Beluga Sand AFE 163398 Page 3 . . psi using water and conduct pre-job safety meeting. MU tool string with 2.70" concave mill, 2%" motor, straight bar, and MHA with circ sub. 9. RIH with milling assembly circulating KCl at minimum rate to 7000'. Get a pickup weight and increase rate to 1.2 bpm. iliote: At 1.2 bpm will have 210 fpm annular velocity. Schlumberger motor is a 2%" XP-PowerPak: 20 to 50 gpm, 150 to 350~m, 600 psi dP, 14 hp). RIH, mill through the Fasdrill bridge plug at 7595'. Check PU weight after milling through plug, continue in hole to PBTD of 8411'. Circulate BU. Check returns for propp ant. l.f --8 \ ~ 10. Drop a ball to open the circulating sub. When the circulating sub is open, cease circulating water and get a tank strap. Begin circulating nitrogen at 1500 scfm, unloading the well to the Johnson tank. Hold back-pressure as per Completion Engineer's schedule to maintain constant BHP during jetting. Jet well dry, shut off nitrogen, POOH. RDMO coil tubing and nitrogen unit. 11. Have Vetco once again grease all tree valves. Continue to avoid using the master valves whenever possible. 12. RU SPIDR gauge to continuously monitor tubing pressure. Flow well through sand buster and through Unocal test separator as per instructions of Completion Engineer. Permanent wing valve and hydraulic SSV should remain shut and flagged. Take gas to flare until pressure and gas rate is adequate to switch to sales. Dump sand buster frequently, and use vacuum trucks to haul off fluids to the tanks on the G&I pad. PTS will provide two flowback hands for 24-hour coverage. Unocal will provide other testing manpower as needed. Pump methanol and use line heater as needed to prevent freezing. Record flowback pressure, gas and fluid rate, flowline temperature, and estimate of solids production at least hourly. Capture fluid samples as per Protechnics' recommendation to analyze for chemical tracer. 13. When the well has sufficiently cleaned up, open the permanent wing valve and hydraulic SSV to route production directly to the production facility. Close the temporary wing valve, bleed off pressure, and RD the pneumatic SSV, sand buster, and other flowback equipment. Install a blind flange on the open wing valve. iliote: The extra wing valve on the flow cross of HV-9 can be removed at some later date during a shut-in.) Produce well to sales. RDMO temporary flow test equipment. Clean out solids and liquids from both flowback tanks and the test separator and dispose via Class II well. Perform a follow-up radiation survey in the temporary and permanent flowback equipment that was tested previously. HV -9 Frac Prog December 10, 2004 . . API: 50-231-20027 AOGCC: 204-170 1104'FSL,1300'FEL Sec22 , T2S, R13W, S.M. RT-THF: 16.4' Tbg lift threads - 3%" IBT Tree cxn - 2%" Bowen cxn Production Tubina: 3Y:z", 9.2 ppf, L-80, IBT-Mod to 3083' - Annulus loaded with 3% KCI brine plus corrosion inhibitor Completion - Chemical injection side pocket mandrel at 2495' (Macco SF01-CI) with 1/4", 0.049" wall SS chemical injection line - Locator sub at 3049" - Baker 80-40 seal assembly 13' of 4.00" OD seals - Muleshoe at 3083' Slickline tag fill at 8336' MD on 11/22/04 Directional Data: max hole angle = 50.5 deg at 3595' KOP = 205' max doglegs = 6.4 deg/100' at 298' 8.0 deg/100' at 1350' 5.2 deg/100' at 1800' HV-9 Actual schematic 11-22-20042 · · · · · · · · · · · · · · · ... . Well Name: Happy Valley #9 Field: Deep Creek Unit State: Alaska Conductor: 13%", 72 ppf, L-80 to 73' /" Surface Casing: 7", 26 ppf, L-80, BTC-Mod to 3297' Cmnt with 137 bbl of 12.8 ppg lead and 17 bbl of 15.8 ppg tail "G". Performed two cement top-jobs (51./" bbl and 4 bbl) /" /' Open Perfs: T-5: 7440' - 7470' (6 spf, 11/8/04) . T-5: 7490' - 7500' (6 spf, 11/8/04) T-7: 7680' - 7700' (6 spf, 11/8/04) T-8: 7760' - 7786' (6 spf, 11/8/04) T-10: 7837' - 7867' (6 spf, 11/8/04) T-17: 8218' - 8237' (6 spf, 11/5/04) Isolated Perfs none Production Liner: 3Y:z", 9.2 ppf, L-80, IBT-Mod liner from 3071' - 8476' Baker ZXP packer, Flexlock liner hanger & 80-40 sealbore at 3046' Cemented with 189 bbl of 12.0 ppg Litecrete Updated by: JGE . . Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.col11 UNOCALŒØ Debra Oudean G & G Technician Date: December 2, 2004 To: AOGCC Helen Warman 333 W, 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL B- WELL LOG TYPE SCALE DATE LOGGED LINE FILM CD NOTES ~.I("I (1 /STÄr. 1 - - ... ··IPERFOFVÙINGRECORD2;'2006PJ-6SPF- ¡5INCHI9/1iï2004[8668-8856uT1' 1'1[1· f' ...... .........n. ,~STAR·1--~'~-ICOM¡;LEOONREcoR62-.5-HSD-powERjETS[51NCHI9/1'1-ï2004l8274-8552-----·¡--j---¡----£I=(I-=.====.== J.u.¡.. 1 HAPPYVALLEY-5rSlIM CEMENT MAP TOOL- -[SlNCH -r10/20/2()Ö4[700.418~!11~L1_r__________.__., (}o ,_ :HAPPY VALLEY·7 [COMPLETION RECORÒ- 2.25 HSD~--[5 INCH[8Ii412004[9998~'Oö18['111·11 r i. ~ol{ "/O'{1 i IpOWERJETS I I I I ¡HAPPY VALLEY·7 ¡MD MUDLOG .. '12 INCH I 7/14/200411008,10274 i1¡-O[ 1 I ,\ fHAPPY VALLEY·8 COMPLETION RECORD 2.5 2506 PO.WERJET.15INCH 8/26/200.415688'6799 [1""nn--l \"'\J HSD 6 SPF I I I ~Ù;\ :HAPPY VALLEY·8 IMD MUDLOG 12 INCH I 7/30/2004[78-8900-[1-' 0[1-1==__ ! ~tr\ !HAPPY VALLEY·8 TVD SONIC QUAD COMBO /2INCH.1 7/31/2004[20.8892 . i1[ or 1 [COMBINED i ¡HAPPY VALLEY·8 IMD SONIC QUIAD COMBO 12 INCH I 7/31/2004120-8892 ro- 0 ¡ON CD ! [RmEsDATAVIEWER . r---I I -ro-lOT1T- HAPPY VALLEY·9 ¡COMPLETION RECORD 2.5 HSD POWERJETS ¡5INCH 111/5/200417390.8362 i111['11 ¡ !..HAPPY VAL LEy:g- .I:ARRA Y IND ÜCTION/ THREË·lITHO~-ENSITY 2INCH'-I'9/23/2004ï-8468- i'-j-11-ïT-----¡ l\~ i / COMPENSATED NEUTRON / BHC SONIC [ ! ~ \ · TVD rlCOMBINED : . ¡HAPPY VALLEY·9 ARRAY INDUCTION /THREE·lITHO·DENSITY 1:~5 . 9/23/200410-8468 1'--1 0 ON CD I. ~. I / COMPENSATED NEUTRON / BHC SONIC INCH . ~U! i PLATFORM EXPRESS ! 'f ¡HAPPY VÃLLEY·9 ~~~FORATION RECORD 2.5 HSD 2506 PJ 6 ¡5INCH r1l8ï2õ04744'0-7837 11[~1r-I-j ;HAppy VALLEY·9 ISlIM CEMENT MAPPING TOOL ¡5INCH 111/1/2004[2900.839~i11r 1 I J ~APPY'VACLEY·9 '[SLIM-cáAENT Mþ:ppiNG-iOOL------~I~~~__[9/17ï2Õ(E[ö=3?06-1-1~[-1T1·r------I Please acknowledge receipt by signing and returning 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 3, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 HAPPY VALLEY 9 1 o Ow 0 o z Ü CD o ~ z 000 ü o Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: I I~ { " LJ ..,- ì A--t, . f/'-.-1' U é} ,'1 j /·7" ;,/\ Iv....{ - \J I ,:;::t I ;" í ,IZ · . ~ u ~ u Œ mJ ~ ~ ~ iÆ ~ [[ ~ / FRANK H. MURKOWSKI, GOVERNOR / AI.ASKA. OIL AND GAS /. CONSERVATION COMMISSION Phil Krueger Drilling Manager Unocal PO Box 196247 i\nchorage,AJ( 99519 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Happy Valley #9 Unocal Permit No: 204-170 Surface Location: 1104' FSL, 1300' FEL, Sec. 22, T2S, R13W, SM Bottomhole Location: 724' FSL, 365' FEL, Sec. 21, T2S, R13W, SM Dear Mr. Krueger: Enclosed is the approved application for permit to drill the above referenced development well. 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. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. Unocal assumes the liability of any protest to the spacing exception that may occur. 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 Commission to , itness any required test. Contact the Commission's petroleum field inspector at (907) 659- 0 (pager). BY ORDER OF THE COMMISSION DATED this.1Q day of September, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. wGÆ- q liD 1 z..vl' 4- 1 a. Type of Work: Drill l.:::J Redrill U 1 b. Current Well Class: Exploratory D Development Oil D ~ultiple Zone LJ Re-entry D Stratigraphic Test D Service D Development Gas o Single Zone D 2. Operator Name: 5. Bond: Blanket 0 Single Well D 11. Well Name and Number: Union Oil Company of California (Unocal) Bond No. 5534278 Happy Valley #9 3. Address: 6. Proposed Depth: ( 12. Field/Pool(s): PO Box 196247, Anchorage, Alaska, 99519 MD: 8465 TVD: 7000 Beluga / Upper Tyonek 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1104' FSL, 1300' FEL, Sect 22, T2S, R13W, SM / C-061590 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 888' FSL, 1514' FWL, Sect 22, T2S, R13W, SM NA 9/13/2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest 724' FSL, 365' FEL, Sect 21, T2S, R13W, SM 3040 Property: 365 4b. Location of Well (~ate Base P~~~ç¡$ates): ,Ii> :f* €/"' ¿'1 10. KB Elevation 15. Distance to Nearest Well Surface:x- 227963 y- 18 9 Zone- 4 (Height above GL): 16.5 feet Within Pool: 1180 16. Deviated wells: Kickoff depth: 250 feet / 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 48 degrees / ./ Surface: 2065 ./ Downhole: 3129 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f.orsacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (incl~ding stage data) NA 13-3/8 68 K-55 Weld 40-80 0 o 40-80 40-80 / .... Driven 8.5 7 26 L-80 Butt-ABM 3838 0 0 3838 (2~ 130 bbls (50 % excess) 6.125 3.5 9.3 L-80 Butt-ABM 4865 3600 2790 8465 7000 155 bbls (30% excess) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD rvD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth rvD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ~ Drilling Program ~ Time v. Depth Plot ~ Shallow Hazard Analysis U Property Plat 0 Diverter Sketch D Seabed Report 0 Drilling Fluid Program 0 20 Me 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 9/8/2004 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Phil Krueger Title Drilling Manager - - _" II:.....' , ,,~/~/ 1,/<2. h Rf:.Llt:.\ V '-'"' Signature Phone 263-7628 Date 9L8/~0.Q~ II / II / Commission Use Only ~ --..:y LUU' Permit to DPIII API Number: Permit APpro~f.. L.I ;~ee COvtd_SiSI\~er Number: 20<1 /·76 50- 23 ì - ;z.. C:>O¿ 7 - CD Date: ~/j,.L. I I Œ\ & G ~g~r'nents. Conditions of approval: Test- ßo Pi: to "5DOO f$i. ' I ""en\!' ö,," Samples required Yes 0 No r&1 Mud log required Yes 0 No ~ ~- - 1-' M Hydro,O" ,,'fido "'":ir' . Yeo 0 No W D;re,\;ooa! "<Ve>' 'l'q";~ Yes ~ No D Olho" ,~I\ s · ,,~'" (h z. , ~ V e-f t 'f · i:lb "" ..;< ~ t Jir. '''''' V ~ . ; s (~t' wiled, t4 .. ), C'';'S (..1-\.) ,) ~ ~ tw~<. e. / Pi: tes €¡/'uv<..c4 '(::.A' '" BY 0 D R 0 9hð/A~ Approve by: 1 I L _ _ . _ I ~ TklE,ç""'MISSION Date: )W 'II \---- UK' \J H'JJ-\L ~I 7 I Fo -40 ~ed 12/2003 Submit in Duplicate .... STATE OF ALASKA .. ALA"OIL AND GAS CONSERVATION COMMWJN PERMIT TO DRILL 20 AAC 25 005 . . Happy Valley #9 Bullet Procedure Install cellar for containment wI 13-3/8" conductor string Prepare pad & install liner, tankage & berms Turnkey rig move from Red Pad, Including NU & Test BOP's Rig Acceptance. H9~~re-spud & ~ES meetings. I. 'G A.. P/U portion of BHA'" L- fJ u.. ~ FeC. t r:.O f E v--,n~ . Clean out conductor & drill out shoe PU remainder of BHA & drill string Drill 8-1/2" hole from: 0' to: 3838' MD I 2950' VD / Circ clean & pump carbide indicator Pump out to BHA & POH LID BHA Clean rig floor & RU to run 7" csg / RIH wI 7" surface casing / Land casing, M/U head, establish circulation RU to cement & conduct safety meeting Pressure test lines & cement 7" casing RD casing running equipment Test BOPE to 250 I 3,000 psi RIH w/6-1/8" steerable BHA Drill out & perform LOT Drill 6 1/8" hole from: 3,838' MD to: 7,000' VD I 8,465' MD / Circulate sweep, SIT, check for swabbing, etc. POH (assumes pump out required due to swab) RU SWS E-line unit, run PEX + Sonic -" RIH, C&C, POOH & LID DP Less 3,800' RU & run 3 1/2" Liner / RIH wI 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 Completion Brine POOH LD DP. RU E-line. RIH and Pull Bond Log. ' RD E-line. & 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=227,963.617 E, Y=2,189,648.61 I Lat: 59° 59' 07.506" N, Long: 151° 29' 07.755" W 1104'FSL, 1300'FEL,Sec22,T2S, R13VV,S.M. UNOCAL8 KB 16.5' AGL GL = 716' AMSL RKB elevation = 732.5' AMSL Happy Valley #9, Kenai Peninsula 13-3/8" 68 ppf butt welded, drilled/driven to +/-30-50' BGL 3-1/2" 9.3 ppf L-80 BTC A.B. Mod Liner from 3600' MD to 8465' MD/7000' VD Liner Cemented with 12.0 Litecrete from 8467' up to 3,500' + 30% excess. Planned TD 8,465' MD /7,000' VD Static BHT = 36.8°F + (0.0136 x TVD) Job Template #1 REVISED: 09/08/04 DRAVVN BY: SSL . . 5. Kenai Gas project Happy Valley #9 3-1/2" SHOE DESIGN SUMMARY & SKETCH 7 "shoe 2,934 ft BML (2,950 ft rvD) 6-1/8" Hole mdb/01 decOO METHOD 2: RT - MSL = 16.5 ft we = 0 ft with 0.447 PSI/FT Gradient DESIGN DOWN: MW = 9 PPG Pform = 9.5 PPG EMW KT = 20 BBLS at 0.5 PPG FG = 0.78 PSI/FT Gas Gradient = 0.02 PSI/FT Drill Pipe = 4 INCH 7 "shoe The shallowest 3-1/2" shoe depth = 2,704 ft BML or 2,721 ft TVD .. \ I \ I \ ---. I The deepest 6-1/8 in hole \ that can be drilled = I 7,654 ft BML or 7,670 ft TVD \ I \ 6-1/8" Hole I \ I \ I \ I \ TD = 6,984 ft BML or 7,000 ft TVD I METHOD 1: ¡DESIGN UP: MW=9PPG Pform = 9.5 PPG EMW KT = 20 BBLS at 0.5 PPG FG = 0.78 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 Casing 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: 0.05) Kick Intensity (Swab kick = 0.0 ppg intensity) Mud Weight Estimated Formation Pressure at Next Section TD Fracture Gradient Kick Tolerance Drill Pipe Outside Diameter Calculation results acceptable. Minimum shoe depth = 2,721 ft TVD RKB S. Kenai Gas project Happy Valley #9 16.5 ft Oft 0.447 psilft 3-1/2 inch 6-1/8 inch 6-1/8 inch 7,000 ft TVD RKB 6,984 ft TVD BML 0.050 psilft 0.5 PPG 9.0 PPG 9.5 PPG EMW 0.78 psilft 20.0 bbl 4 inch 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 Calculation results acceptable. Maximum shoe depth = 7,670 ft TVD RKB mdb/01decOO 7 inch 2,950 ft TVD RKB 2,934 ft TVD BML 0.020 psilft 6-1/8 inch 0.5 PPG 9.0 PPG 9.5 PPG EMW 0.78 psilft 20.0 bbl 4 inch 7132 . . UNOCAL Maximum Anticipated Surface Pressure Calculation Happy Valley Well #9 Kenai Peninsula, Alaska Assumptions: ./ 1. Based on offset drilling & well test data, the pore pressure gradient is predicted to be a 0.447 psi/ft gradient from surface to planned total depth at 7,000' VD BRT. 2. The MAS.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 #9 will be at the same depth as the shoes in HV well #8 thus the nearby LOT data from approximately 2653' VD is useful for relatively accurate kick tolerance & MASP calculations. 3. The MAS.P. during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD & the surface. M.A.S.P. During Production Life: ~I ./ 7,000 ' VD x = 3129 psi 3129 psi - (0.096 psilft * 7,000 ft) = = 2457 psi Max. pore pressure at T.D. = MAS.P. (tbg leak at surface) = M.A.S.P. While Drilling 6-1/8" hole at 8,465' MD: Max. Est. Frac pressure at 7" shoe = 2950 ft. x 0.78 psi/ft* = = 2301 psi ,,/ = fô65 / psi ~ V MAS.P. during drilling = 2301 psi - (.08 psilft x 2950 ft.) = WELL: Happy Valley #9 Calculation & Casing Design Factors FIELD: South Kenai Gas Sect. 1 8 1/2" hole MUD WT. Sect. 2 6-1/8" hole MUD WT. 9.1 PPG MASP= 2,065 psi 9.3 PPG MASP= 2,457 psi DESCRIPTION GRADE THREAD / SECTION CASING BOTTOM TOP LENGTH WT. 7" 3.838 0 3838 26 TVD 2,950 0 2 31/2" 8,465 3650 4815 9.2 TVD 7,000 2757 ./ L-80 BTC-mod IBT-mod 44,298 99,788 L-80 Happy Valley Well #9 Kenai Peninsula, Alaska DATE: 7-sep-04 Production Mode WEIGHT W/OBF LBS TENSION TOP OF SECTION LBS 99,788 44,298 MINIMUM STRENGTH TENSION 1000 LBs 979 207 DESIGN BY: Steven Lambe COLLAPSE COLLAPSE PRESS @ RESIST. WORST CASE BOTTOM w/o TENSION WORST CASE SF TENSION PSI* PSI SF COLL. / /' 9.81 1,298 3,090 2.38 4.67 3,080 10,530 3.42 ** See attached sheet for calculation of MASP * Collapse pressure is calculated; Normal Pressure Fluid Gradient for external stress (.44 psi/ft) and the casing evacuated for the internal stress (0 psilft) Note: All wellhead components are rated to 5000 psi working pressure. . MASP PSI** MINIMUM YIELD WORST CASE PSI SF BURST /~ 3,717 5,750 1.55 3,717 10,160 2.73 . . . Property arids and formulas for Happy Valley #9 Surface Hole Recommendations- Surface Interval- (0 - 3,838' MD) Mud Type: 6%KCI, EZ Mud P rt' rope les: Densitv Viscosity Plastic Viscosity Yield Point API FL R.!:! 0-1200' 8.6 - 8.9 ,/ 60 - 85 6 - 16 35 - 45 <8 8.5-9.0 System Formulation: Product Water KCI KOH Barazan D PACL EZ Mud DP Aldacide G Baracor 700 Barascav D 6%KCI, EZ Mud Concentration 0.905 bbl 20 ppb (30K chlorides) 0.2 ppb (9 pH) 1.5 -2 ppb (as required 35-45 YP) 1 ppb 0.75 ppb 0.1 ppb 1 ppb 0.5 b (add as the well suds Special Mixing Instructions: · Mix in order as listed · Add polymers slowly to minimize fisheyes. Production Hole Recommendations-Interval (61/8" hole, 3.5" casina ): 0 to 8876' MD Mud Type: 6%KCI, EZ Mud Properties: 4600 - 8876' Plastic Viscosity 6 - 15 Yield Point 15 - 25 API FL <5 R.!:! 8.5-9.0 System Formulation: Product Water KCI KOH Barazan D Dextrid PACL 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 1 ppb 0.75 ppb 0.1 ppb 1 ppb 0.5 b maintain er dilution rate Special Mixing Instructions: · Mix in order as listed · Add polymers slowly to minimize fisheyes. " . Happy Valley Well #9 BOP Stack Diagram Underside of Rota Table Planned Test Pressure 3,000 psi I .. .. Ground Level / 7" x 3-1/2" outlet 11"SMMBS ./ Wellhead ~ SOW 13-3/8" x 68# _ Conductor (driven) 2)'thíckbaseo)àtè .. ~. 10'0" Note: Top of Lower Master Valve (or temporary cap) must be <2' AGL to skid derrick. (M.t:." 8' or 96" unnn_tn~~" --------- --- "alea Gray DRAWN BY: J. HRADECKY ENG. APPR.: 3-118 SM 3-1/8 SM 11 SM ~ 13-3/8' OD CSG 7' OD CSG 3-112' OD TBG SWE & FCE ENGINEERING 13-3/8 X 7 X 3-1/2 DD, 5M MSP ASSY DATE: 27 AUG 04 DATE: UNOCAL ALASKA HAPPY VALLEY PROJECT NA PROJECT NO.: ACAD DRAWING NO. SP-4912 HAPPY VALLEY #9 PLAN DAYS VERSUS DEPTH UNOCAL 1,000 2,000 . 3,000 4,000 5,000 Z' ~ 6,000 ~ '-" ..= 7,000 ~ Q., ~ ~ 8,000 9,000 10,000 . 11,000 12,000 13,000 14,000 0 5 10 20 30 25 15 Time (Days) HV #9 AFE DAYS Happy Valley #1 )Ie Happy Valley #9 Actual w .. w Actual Cost I Happy Valley #8 I I" If '" , .. _ \.. _, ......_. I .... I ¢:: 0 -400 0 N II E u 0 () ro u CI) 400 800 1200 1600 2000 2400 - - () () :=. 2800 = C. () 3200 C -æ u 3600 :;::::I ~ ~ 4000 () ::s ~ I- 4400 . V 4800 5200 5600 6000 6400 6800 7200 7600 ... IS 1-- UNOCAL INTEQ Location: Kenai Peninsula, Alaska Slot: HV#9 Field: South Kenai Gas Field Well: HV#9 Installation: Happy Valley Wellbore: HV#9 Ver 1 Scale 1 cm = 300 ft East (feet) -> . UNOCAL -6000 -5400 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 ~ Q' 01'" 'Ýo/, Q' DLS: 3.50 deg/100ft 28.00 35.00 42.00 End of Build a? ~. ~ <-:; Q'o @..... 7'<) (~----- >~ o '.. ~ 7" Casing End of Hold Þ Beluga 40 Tgt .>. 0. ~@/, 'I'\!}.. ~ "09 'I'~ OJ-. 09(' ;/ 37.44 33.44 DLS: 2.00 deg/100ft 25.44 End of Drop WELL PROFILE DATA Point MO Inc AzI TVO North E;lst deg/10Oft V, Sect Tie on 0.00 0.00 265.00 0.00 0.00 0.00 0.00 0.00 KOP 250.00 0.00 265,00 250.00 0.00 0.00 0.00 0.00 End of Build 1621.43 48.00 265.00 1466.54 -47.21 -539.58 3.50 541.64 End of Hold 3913.13 48.00 265.00 2999.99 -195.64 -2236.16 0.00 2244.70 Target HV#9 - Beluga 4 4241.23 41.44 265.00 3233.00 -215.75 -2466.02 2.00 2475.44 End of Drop 5063.12 25.00 265.00 3918.23 -254.86 -2913.04 2.00 2924.17 ./ v T.D. & Target HV#9· TD 8463.49 25.00 265.00 7000.00 -380.11 -4344.63 0.00 4361.23 3 1/2" Liner o 600 1200 1200 600 ~ 1-0,0 Q' Ol'"~ ~lo- ^ . -0 Z o ;:¡. -600 ::r ~ CÐ - -1200 'r1r' £ ëD -1800 ~ " '" o o -2400 ;:! Created by: Planner Date plotted: 8-Sep-2004 Plot reference is HV #9 Ver 1. Ref wellpath is HV #9 Ver 1. Coordinates are in feet reference HV #9. True Vertical Oepths are reference Rig Oatum. Measured Depths are reference Rig Datum. Rig Oatum: Oatum #1 Rig Oatum to mean sea level: 732.50 ft. Plot North is aligned to TRUE North. V" ~ TD -400 -0 400 Scale 1 em = 200 ft 800 1200 1600 2000 2400 2800 3200 3600 4000 Vertical Section (feet) -> Azimuth 265.00 with reference 0.00 N, 0.00 E from HV #9 4400 4800 ... UNOCAL UNOCAL BAKER HUGHES Location: Kenai Peninsula, Alaska Slot: HV#9 INTEQ Field: South Kenai Gas Field Well: HV#9 llnstallation: Happy Valley Wellbore: HV #9 Ver 1 East (feet) -> Scale 1 cm = 20 ft -840 -800 -760 -720 -680 -640 -600 -560 -520 -480 -440 -400 -360 -320 -280 -240 -200 -160 -120 -80 -40 0 40 240 1 240 ~ :I: -< ~'\ó-\ 1> 200 1 210}" \ 1500 200 2000 "--_ ' 1900..' 160 1700 s¿0Y¡éJ 160 HV#1 761 120 . 120 7.!b 1/0 ~7. ~oa 1/ ~~Q 00 1/ ~ù! v 80 ~"é;¡ °0 80 ~ò) v ~6à 1/0 ~.>- v 40 ~ó'Q 00 40 ~.9Q 1/ ú'Q V ó'°o ^ 0 ú'7. Vo 7a .900 0 ^ I Vo I :P' ~ 00 Z Q) HV#1 ú'J! °0 0 ~ -40 ú'''é;¡ 1/0 7 77. ~oo -40 :+ - v 7J! ~oo 00 7. 7 "é;¡ ::r = 7"é;¡ 1/0 - 76à 76) 6òo v cr ... 1/ 7.>- 00 0 -80 76à v 761 00 -80 CD Z 7.>- Vo - v 7& - 00 ~a Vo -120 ~7. 1/0 -120 00 ", -160· ~~oo -160 l ~ù! °0 ~"é;¡ v -200 ~ò) -200 °0 ¡¡: ~6) en ~ -240 DO -240 £ ~.>- ¡þ II 00 § ~c9a 0 .... -280 v - -280 3 OJ II Ci'i ~.9'b N 0 0 en -320 I ~---,-----¡ I ,,-,-,- -320 ;:! -840 -800 -760 -720 -680 -640 -600 -560 -520 -480 -440 -400 -360 -320 -280 -240 -200 -160 -120 -80 -40 0 40 Scale 1 cm = 20 ft East (feet) -> UNOCAL UNOCAL Created by: Planner Date plotted: 8-Sep-2004 Plot reference is HV #9 Var 1. Ref wellpath is HV #9 Var 1. Coordinates are in feet reference HV #9. 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#9 Field: South Kenai Gas Field Well: HV#9 Installation: Happy Valley Well bore: HV #9 Ver 1 TRUE NORTH INTEQ 350 o ~ 'X. 400 , '-,300 --··,.200 r::,'" 1:>'" #' ~ <j '\<§> E> 10 340 20 200 300 330 30 <f>'" , _ ,.....9,;;.-~Ö;,._. - 40 <§>'" " -7.-~ 000.E'.) .~ 320 ->00 d'°o 310 50 6'q, 6'Q VE.> 60 290 70 280 80 270 2 0 1 0 1 0 2 0 .- 90 7)'. 00 260 100 250 110 240 120 230 130 220 140 1 0 210 2 0 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Wel . . u..e.... UNOCAL ,HV #9 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 1 Wellbore: HV #9 Ver 1 Wellpath: HV #9 Ver 1 Date Printed: 8-Sep-2004 INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 732.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 265.00 degrees Bottom hole distance is 4361.23 Feet on azimuth 265.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . all..... UNOCAL ,HV #9 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Well bore: HV #9 Ver 1 Well path: HV #9 Ver 1 Date Printed: 8-Sep-2004 INTEQ 100.00 0.00 265.00 100.00 O.OON O.OOE 0.00 0.00 227963.26 2189648.62 200.00 0.00 265.00 200.00 O.OON O.OOE 0.00 0.00 227963.26 2189648.62 250.00 0.00 265.00 250.00 O.OON O.OOE 0.00 0.00 227963.26 2189648.62 350.00 3.50 265.00 349.94 0.278 3.04W 3.50 3.05 227960.21 2189648.42 450.00 7.00 265.00 449.50 1.068 12.16W 3.50 12.20 227951.08 2189647.83 550.00 10.50 265.00 548.32 2.398 27.31W 3.50 27.41 227935.90 2189646.84 650.00 14.00 265.00 646.03 4.248 48.44W 3.50 48.63 227914.73 2189645.47 750.00 17.50 265.00 742.26 6.608 75.48W 3.50 75.77 227887.65 2189643.71 850.00 21.00 265.00 836.66 9.488 108.32W 3.50 108.73 227854.76 2189641.57 950.00 24.50 265.00 928.86 12.858 146.84W 3.50 147.40 227816.17 2189639.07 1050.00 28.00 265.00 1018.54 16.708 190.89W 3.50 191.62 227772.05 2189636.21 1150.00 31.50 265.00 1105.34 21.028 240.31W 3.50 241.23 227722.54 2189632.99 1250.00 35.00 265.00 1188.96 25.808 294.93W 3.50 296.05 227667.83 2189629.44 1350.00 38.50 265.00 1269.07 31.028 354.52W 3.50 355.88 227608.14 2189625.57 1450.00 42.00 265.00 1345.38 36.658 418.88W 3.50 420.48 227543.67 2189621.38 1550.00 45.50 265.00 1417.61 42.678 487.76W 3.50 489.62 227474.68 2189616.90 1621.43 48.00 265.00 1466.55 47.218 539.58W 3.50 541.64 227422.76 2189613.54 1700.00 48.00 265.00 1519.12 52.308 597.75W 0.00 600.03 227364.50 2189609.75 1800.00 48.00 265.00 1586.03 58.778 671.78W 0.00 674.35 227290.34 2189604.94 1900.00 48.00 265.00 1652.94 65.255 745.81W 0.00 748.66 227216.18 2189600.13 2000.00 48.00 265.00 1719.86 71.738 819.84W 0.00 822.97 227142.03 2189595.31 2100.00 48.00 265.00 1786.77 78.208 893.87W 0.00 897.29 227067.87 2189590.50 2200.00 48.00 265.00 1853.68 84.688 967.91W 0.00 971.60 226993.71 2189585.69 2300.00 48.00 265.00 1920.60 91.168 1041.94W 0.00 1045.92 226919.56 2189580.87 2400.00 48.00 265.00 1987.51 97.648 1115.97W 0.00 1120.23 226845.40 2189576.06 2500.00 48.00 265.00 2054.42 104.118 1190.00W 0.00 1194.55 226771.24 2189571.25 2600.00 48.00 265.00 2121.34 110.598 1264.03W 0.00 1268.86 226697.08 2189566.43 2700.00 48.00 265.00 2188.25 117.078 1338.06W 0.00 1343.18 226622.93 2189561.62 2800.00 48.00 265.00 2255.16 123.548 1412.10W 0.00 1417.49 226548.77 2189556.81 2900.00 48.00 265.00 2322.08 130.028 1486.13W 0.00 1491.80 226474.61 2189551.99 3000.00 48.00 265.00 2388.99 136.508 1560.16W 0.00 1566.12 226400.46 2189547.18 3100.00 48.00 265.00 2455.90 142.975 1634.19W 0.00 1640.43 226326.30 2189542.37 3200.00 48.00 265.00 2522.82 149.458 1708.22W 0.00 1714.75 226252.14 2189537.55 3300.00 48.00 265.00 2589.73 155.938 1782.25W 0.00 1789.06 226177.98 2189532.74 3400.00 48.00 265.00 2656.64 162.418 1856.29W 0.00 1863.38 226103.83 2189527.93 3500.00 48.00 265.00 2723.55 168.888 1930.32W 0.00 1937.69 226029.67 2189523.11 3600.00 48.00 265.00 2790.47 175.36S 2004.35W 0.00 2012.01 225955.51 2189518.30 3700.00 48.00 265.00 2857.38 181.84S 2078.38W 0.00 2086.32 225881.36 2189513.49 3800.00 48.00 265.00 2924.29 188.31S 2152.41W 0.00 2160.63 225807.20 2189508.67 3900.00 48.00 265.00 2991.21 194.79S 2226.44W 0.00 2234.95 225733.04 2189503.86 39J3.13 48.00 265.00 2999.99 195.648 2236.16W 0.00 2244.70 225723.31 2189503.23 4013.13 46.00 265.00 3068.19 202.01 S 2309.02W 2.00 2317.84 225650.33 2189498.49 4113.13 44.00 265.00 3138.89 208.18S 2379.45W 2.00 2388.54 225579.77 2189493.91 4213.13 42.00 265.00 3212.03 214.12S 2447.39W 2.00 2456.74 225511.72 2189489.50 4241.23 41.44 265.00 3233.00 215.75S 2466.02W 2.00 2475.44 225493.06 2189488.28 4341.23 39.44 265.00 3309.11 221.408 2530.63W 2.00 2540.30 225428.34 2189484.08 4441.23 37.44 265.00 3387.43 226.828 2592.56W 2.00 2602.46 225366.31 2189480.06 4541.23 35.44 265.00 3467.88 232.008 2651.73W 2.00 2661.85 225307.04 2189476.21 4641.23 33.44 265.00 3550.35 236.93S 2708.06W 2.00 2718.40 225250.61 2189472.55 4741.23 31.44 265.00 3634.74 241.608 2761.49W 2.00 2772.04 225197.09 2189469.07 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 732.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 265.00 degrees Bottom hole distance is 4361.23 Feet on azimuth 265.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . IiINdCÎÎL. UNOCAL ,HV #9 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Wellbore: HV #9 Ver 1 Wellpath: HV #9 Ver 1 Date Printed: 8-Sep-2004 INTEQ 4841.23 29.44 265.00 3720.95 246.02S 2811.96W 2.00 2822.70 225146.54 2189465.79 4941.23 27.44 265.00 3808.88 250.178 2859.39W 2.00 2870.32 225099.02 2189462.71 5041.23 25.44 265.00 3898.42 254.05S 2903.74W 2.00 2914.84 225054.59 2189459.83 5063.12 25.00 265.00 3918.23 254.868 2913.04W 2.00 2924.17 225045.28 2189459.22 5100.00 25.00 265.00 3951.65 256.228 2928.56W 0.00 2939.75 225029.73 2189458.21 5200.00 25.00 265.00 4042.28 259.90S 2970.67W 0.00 2982.01 224987.56 2189455.47 5300.00 25.00 265.00 4132.91 263.58S 3012.77W 0.00 3024.27 224945.39 2189452.74 5400.00 25.00 265.00 4223.54 267.278 3054.87W 0.00 3066.54 224903.22 2189450.00 5500.00 25.00 265.00 4314.17 270.958 3096.97W 0.00 3108.80 224861.04 2189447.26 5600.00 25.00 265.00 4404.80 274.638 3139.07W 0.00 3151.06 224818.87 2189444.52 5700.00 25.00 265.00 4495.43 278.328 3181.17W 0.00 3193.32 224776.70 2189441.79 5800.00 25.00 265.00 4586.06 282.008 3223.27W 0.00 3235.58 224734.53 2189439.05 5900.00 25.00 265.00 4676.69 285.698 3265.37W 0.00 3277.85 224692.35 2189436.31 6000.00 25.00 265.00 4767.33 289.378 3307.47W 0.00 3320.11 224650.18 2189433.58 6100.00 25.00 265.00 4857.96 293.058 3349.57W 0.00 3362.37 224608.01 2189430.84 6200.00 25.00 265.00 4948.59 296.748 3391.68W 0.00 3404.63 224565.84 2189428.10 6300.00 25.00 265.00 5039.22 300.428 3433.78W 0.00 3446.89 224523.66 2189425.36 6400.00 25.00 265.00 5129.85 304.10S 3475.88W 0.00 3489.16 224481.49 2189422.63 6500.00 25.00 265.00 5220.48 307.79S 3517.98W 0.00 3531.42 224439.32 2189419.89 6600.00 25.00 265.00 5311.11 311.478 3560.08W 0.00 3573.68 224397.15 2189417.15 6700.00 25.00 265.00 5401.74 315.158 3602.18W 0.00 3615.94 224354.97 2189414.41 6800.00 25.00 265.00 5492.37 318.848 3644.28W 0.00 3658.20 224312.80 2189411.68 6900.00 25.00 265.00 5583.00 322.52S 3686.38W 0.00 3700.47 224270.63 2189408.94 7000.00 25.00 265.00 5673.63 326.208 3728.49W 0.00 3742.73 224228.46 2189406.20 7100.00 25.00 265.00 5764.26 329.898 3770.59W 0.00 3784.99 224186.28 2189403.46 7200.00 25.00 265.00 5854.89 333.578 3812.69W 0.00 3827.25 224144.11 2189400.73 7300.00 25.00 265.00 5945.52 337.258 3854.79W 0.00 3869.51 224101.94 2189397.99 7400.00 25.00 265.00 6036.15 340.948 3896.89W 0.00 3911.78 224059.77 2189395.25 7500.00 25.00 265.00 6126.79 344.62S 3938.99W 0.00 3954.04 224017.59 2189392.52 7600.00 25.00 265.00 6217.42 348.30S 3981.09W 0.00 3996.30 223975.42 2189389.78 7700.00 25.00 265.00 6308.05 351.998 4023.19W 0.00 4038.56 223933.25 2189387.04 7800.00 25.00 265.00 6398.68 355.67S 4065.30W 0.00 4080.82 223891.08 2189384.30 7900.00 25.00 265.00 6489.31 359.358 4107.40W 0.00 4123.09 223848.90 2189381.57 8000.00 25.00 265.00 6579.94 363.048 4149.50W 0.00 4165.35 223806.73 2189378.83 8100.00 25.00 265.00 6670.57 366.728 4191.60W 0.00 4207.61 223764.56 2189376.09 8200.00 25.00 265.00 6761.20 370.408 4233.70W 0.00 4249.87 223722.39 2189373.35 8300.00 25.00 265.00 6851.83 374.098 4275.80W 0.00 4292.13 223680.21 2189370.62 8400.00 25.00 265.00 6942.46 377.778 4317.90W 0.00 4334.40 223638.04 2189367.88 8463.49 25.00 265.00 7000.00 380.118 4344.63W 0.00 4361.23 223611.27 2189366.14 All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVO's are from Rig ( Datum #1 732.5ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 265.00 degrees Bottom hole distance is 4361.23 Feet on azimuth 265.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . a..Q.. UNOCAL ,HV #9 Happy Valley, South Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 4 Wellbore: HV #9 Ver 1 Wellpath: HV #9 Ver 1 Date Printed: 8-Sep-2004 INTEQ O.OOE 539.58W 2236.16W 2466.02W 2913.04W 4344.63W KOP End of Build End of Hold Belu a 40 T t End of Dro TD HV#9 - Beluga 40 9/8/04 HV#9 - TO Tgt - 380.11 S 4344.63W 7000.00 9/8/04 N59 59 3.75 W151 223611.27 2189366.14 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 Rig ( Datum #1 732.5ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 265.00 degrees Bottom hole distance is 4361.23 Feet on azimuth 265.00 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated UHOUL. . . UNOCAL HV #9 Ver 1, HV #9 Ver 1 HV #9, Happy Valley CLEARANCE LISTING Page 1 Date Printed: 8-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 ft/1 OOOft are not reported Cutoff is calculated on CENTRE to CENTRE distance Summarv data uses Closest Approach clearance calculation for all minima Hole size/CasinQs are NOT included Hole size/Casinç¡s 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 Oatum (0.00) Report uses Revised: (D-C)/E Factor Calculation HV#5 HV#5 Happy Valley 158.34 0.00 0.00 158.28 295.28 37.05 885.83 HV#4 HV#4 Happy Valley 164.95 0.00 0.00 165.54 32.81 48.83 1082.68 HV#1 HV#1 Happy Valley 166.06 0.00 0.00 166.63 32.81 78.82 1000.66 HV#3 HV#3 Happy Valley 171.45 219.00 219.00 170.83 311.68 38.03 984.25 HV#2 HV#2 Happy Valley 186.00 0.00 0.00 186.50 0.00 61.90 984.25 HV#8 HV#8 Ha 238.24 155.66 155.66 238.21 180.45 7.38 2181.76 HV#7 HV#7 Ha 238.76 278.87 278.87 238.29 295.28 55.80 1082.68 All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Oatum #1 732.5ft above mean sea level) Reference MO's are from Rig, Offset MOos are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.56 (10) Prepared by Baker Hughes Incorporated PROPOSED WELL HV#9 / GRID N:2189648.617 GRID E:227963.258 LATITUDE: 59°59'07.506"N LONGITUDE: 151 °29'07.755"W ELEV. 716' """\\" ...... <-. 0 F AI.. · t _... ~~............~C\ " _L~" .'.\J.L, - ~,:., ";,r~ I : * ....49.TI:i '"7* ~ ",................................... ;1 " , " " ;1................................... __ ~ ~ ··.M. SCOTT McLANE:' J ,.. I ",,' .~- I' ").~"'. 4928-5 ..,:~Q;'- I .~~ '. .' Cj - I ()A ............\.....~....- l " 1?ortss I oNþ..\. ........ ,\\\\".......... HAPPY VALLEY NO.1 PAD -.i (f) LL ~ o .- J OILWELL RD. SCALE 1 inch = 300 ft. o 300 450 ~.~ I 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 1300' FEL SECTION 22 TOWNSHIP 2 SOUTH RANGE 13 WEST SEWARD MERIDIAN ALASKA Grid SEC 22 SEC 23 SEC 27 SEC 26 APPLICANT: UNDCAL 909 W. 9th Avenue . Anchora e, AK 99519-7685 HAPPY VALLEY NO.9 WELL AS-STAKED SURFACE LOCATION NINILCHIK, AK 1".0. Box 46B SOLDDTNA, AK 99669 Project: 043070hv9 Consulting ~roup T é?sting Revisions: TEL 907.283.421 B FAX 907.283.3265 Dwg:043070 Date: 8/30/04 FIGURE: 1 . . '" t';;1 C...o61587 "'''''1 ¡.:l.- 11 :2:5 2-~ _______J SURfAœ lOCATIOH Ww't(1f!.1 ;N} :1:1 2f, 25 590 UNOCALe DEEP CREEK UNIT HAPPY VAL.LEY 9 EXHIBIT A "'¡I ..:¡~ -C-061591 '3 + - 0.5 0~25 0 0.5 . c..~ I UiIí'ìS AlS$ka St'8!!e Ptanø Zooe 4. NA.D21 · Unocal Corporation . P.O. Box 196247 Anchorage. AK 99501 Telephone (907) 263-7660 UNOCALe Wednesday, September 08,2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Commission Chair John Norman Re: Application for Permit to Drill (Form 10-401) Happy Valley #9 Dear Commissioner Norman, Attached for your approval is an application for permit to drill (Form 10-401) for the Happy Valley #9 Well. Unocal respectfully requests a waiver of the requirement for a diverter on the 8-1/2", surface hole as allowed under AOGCC Regulation 20 MC 25.035 (h) (2). Please refer to attached supporting documentation. The anticipated spud date is approximately September 13, 2004.'/ If you have any questions please contact myself at 263-7628, or Mr. Steven Lambe @ 263-7637. Sincerely, V~~7¿ ¡ ~tÄ:u~g~r Drilling Manager SSL/s Enclosure RECEI\/Fn SEP - 9 7004- A\aska Oil & Gas Anchorage ORIGINAL . . WAIVER REQUEST Unocal respectfully requests a waivers to AOGCC regulations 20 AAC 25.035 (C) WAIVER #1: Unocal request permission to drill the 8-1/2" surface hole to a depth of +/- 3838' MD/ 2950' VD without a diverter. AOGCC regulation 20 AAC 25.035 (h) (2) stipulates: (h) "Upon 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 offset drilling data of Happy Valley #8, the first indication of gas was recorded in the Beluga formation at 3,100' VD on both the mud logs ,- and Open hole logs. The top of productive gas was encountered @ 3,233' / TVD. The top of Beluga was encountered @ 3010' VD. The composite average permeability in the Beluga is 1.7 md from testing conducted to date. The proposed surface casing depth is above all recorded gas shows, / and the Gas bearing Beluga formation. Happy Valley #9 is within 1200' of HV #8 at the surface casing shoe In addition to having relevant offset data from Happy Valley #8, Unocal will NU the BOPs on the 11" MB directly on the 13-3/8" conductor pipe. In the / unlikely event flow is encountered, the BOP will provide some capability to divert flow from both the choke line via 3" ID. For the purpose of basic risk mitigation, Unocal will utilize a spud mud which is expected to weigh approximately 8.9 to 9.2 ppg when drilling at / / the planned surface hole TD of 3838' MD', 2950' VD, to eliminate the risk of ' a shallow water flow. - tit .:...:..:::. Union Oil Company of California Accounts Payable Field Disbursing Date 08-SEP-04 Void after six months from above date. -:0:1 . .00 20 q_: :I q . .8 . :I 7"· ", tit TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡/íJlj 0tð1 7 PTD# 2Dt/- 176 V' Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ·'CLUEn Tbe permit is fOT a new well bore segment of existing weD· , Permit No, .' API No. Production. should continue to be reported as a function· of tbe original API number. stated above. HOLE )n accordance witb 20 AAC 25.005(f), aU records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTJON V' DRY DITCH SAMPLE Tbe permit is approved su bj ect ·to fun compliance witb 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. fCompany Name) assumes tbe liability of any protest tUhe spacitlj' ~e~c tio ~ ma,. occur. . ¿¿. pt,r-ta . r . ~ ~ AU dry ditch sa p sets submitted to tbe Commission must be in no greater ·than 30' sample interva)s from below tbe permafrost or from where samples are fint caught and 10' sample iIiter:vals through target zones. VIA- pD tJ· , . ðf Field & Pool HAPPY VALLEY. UNDEFINED GAS - 290500 Well Name: HAPPY VALLEY UNIT 9 Program DEV ~_ Well bore seg 0 lOlL CO OF CALIFORNIA Initial ClasslType DEY / PEND GeoArea 820 Unit 50810 On/Off Shore ~_ Annular Disposal 0 Administration Permit fee attached ~ - - - - - - - - - - - - - Yes_ - - - - 2 lease _numberapRrowiate_ _ _ Yes Surt:ace loçatiol1 andJop t¡¡rgeUI1 ClRJ le¡¡~eC-06159Q; TD jn_ CIRlleas_eC_-Q615&9 _ 3 _U_niqueweltn_ame_and lJumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes_ - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WellJQcated ina_d_efil1e_dpool _ - - -- No - - - - 5 WelIJQc¡¡ted proper _distance_ from drilling ul1ilboUl1d_ary_ _ Yes 6 WellJQc¡¡ted pr_oper _distance_ from otlJer wells No SI='ACII'JGEXCEPTIONREQUJREQ: wilLbe jn_ ~amesectiOIJ al1d_ within300Q' o(HV #8, 7 _S_uffjciel1tacreage_aYailable indrilliogunIt - - - - - No 8 J(deviated. js_ weJlbQre plaUocJu_ded _ _ Yes - - - - - - - - - 9 _O-perator OI1I~ affected party _ _ _ Yes 10 ø-pecator lJas_appropr[ateJlond inJorce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - * - - - - - - - - - - - - - - - - - - - - - - - - - - -- 11 Permit C.an be issued wItlJQut COMervation order_ No_ - - - - - - - - - - Appr Date 12 Permit C.an be issued wItlJQut admioistratÎlle_approvaJ _ _ _ - - - - - Yes SFD 9/9/2004 13 Can permit be approved before 15-day wait Yes 14 WellJQc¡;¡ted within area and_strat¡¡_authorized byJnjectioo Ord_er # (putlO# in_commentsJ-{For NA - - - - -- 15 AJI wells_ within Jl4_l1Jite_are.a_of reyiew Identified (FOr ~ervjc.ewe[l onl~>- _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 _Pre.-produ_ced injector; !iur<1tiQn_of pre-Productioo less_ than 3 montlJs_ (For service well QnJy) NA - - - -- - - -- 17 ACMP_findingof Con_sistencyhas Þee_nj~sued for_tlJis project _NA - - - - - Engineering 18 _C9nductor stringprQv[ded _ _ _ _ - - - - - Yes - - - - - 19 _S_urfac.e _casil1g pJotec.t~ all_known USDWs _ _ _Yes - - - - - - - -- 20 _CMT v_ol adequateJo circulate on _cOl1d_uctor_ 8. $U_rf_ csg _ _ Yes Ade~uate exce~s, _ _ 21 CMT vol adequate_ to tie-inJQngstring to surf ~g . Yes 22 _CMTwiIl coyer_aU koownproductiye IJQriZOl1s_ Yes 23 _C_asing de_signs adequa1e for C._T~ B_&permakost Yes - - - - - 24 A!iequ<1teJan_kage_oJ re_serve pit _ _ Yes l'Jab_ors 129. 25 J(aJe-drill~ has_a to:403 fQr <1bandonme_nt been apPJoved _ NA l'Jewwell, 26 _A!iequ<1te-"lo'ellbore ~eparatIo_n-Pfo-posed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Jtdiver:ter require.d, dQes iLmeet reguJations No Waiyeuequested_. _ . - - - - - Appr Date 28 _DJilIiog fluId_ program sc.hematic_& equip Jistadequale _ . Yes Max MW9~2 ppg._ _ . - - -- WGA 9/10/2004 29 _BOPEs._d_othey meet reguJatioo _ _ . Yes 30 BOPEwess raliog appropriate; Jest to (puJ p~ig in _commel1ts)_ Yes Test to_30QO_ RSi. _MSF' 2065 psi. - - -- -- 31 _Choke manIfold cQmpJie~ w/API RF'-53 (May 84) Yes - - - - - - -- 32 WQrk wiJl OCCUr withouLoperationslJutdown - - - - - Yes - - -- 33 J~ Rre~ence_ Qf HZS gas_ prQQable . No 34 Meçbanical_coodjtion otwe.lIs within AOR yerified (For_service well only) NA DevelopmenJ well. . - - - - - - - Geology 35 Permit can be issued wlQ hydrogen s_ulfide meas_ures Yes - - - - - 36 _D_ata_preseoted on_ Rote_ntial oveJRres_Sure _ZOl1es_ _Yes Expected pre~sure -9ra_dient is "nO(l'1'!aJ: 1O.447.psi/ft) Appr Date 37 _Seismic_analysJs_ Qf sbaJlow gaszooe.s_ _ . NA WelJ wiJI be 9th drifted from thj~ Rad._ - - -- SFD 9/9/2004 38 _SeabedcOl1dItioo survey _(if Off-~hore) _ _ _ . NA - - - - - 39 _ CQnta_ct l1amelphol1eJorweekly progre~ueports [exploratory only). NA - Geolo! Engineering Date Commiss Commissioner fJJJ e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, 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. HAPPY #9 Deep eek Unit er Cook Inlet, Alaska FINAL ELL T September 2004 Lees Browne, Jr. - Sr. Pokrovsky - Logging Geologist - I . . . UNOCALe Happy Valley #9 TABLE OF CONTENTS WELL RES UME .. ................ ......................................... ..... ............... ......... ........... ......... ......... II" ............................... ....,.. ..... ............................... 3 PROCEDURES and GENERAL DISCUSSION... ........... .......... ....................... .........................................5 GEOLOGICAL DiSCUSSiON...... ............ .................................................... ............ .......... ...................... 6 DAILY ACTIVITY SUMMARY.. ...................... ............. ............................................................................. 7 LITHOLOGY REVIEW.. ........~........., .... ..... .............."...... ........................................................................... 9 SURVEYS .............................. ............ .................................. ..... ... ...... ... ............. ...... ............. ............. .... .......... ..... ....... ....... ... ............. 18 DAILY MUD PROPERTIES ................................. .................................... ................................... ........... 22 BIT RECORD ...................... ...... ......................... .............................................................................. ,......23 MORNING REPORTS ..... ... ................... .... ............. .... ... ................................... .................. .............. ..... 24 FINAL WELL LOGS..... 10:........... ...... .....".... ......... .... ..... ..... ......... ... ........ II ..... ............ ......... ..... ... APPENDIX I fI El)()CH 2 UNOCALe Happy Valley #9 · WELL RESUME Company: Unocal Alaska Resources, Inc. Well: Happy Valley #9 Field: Deep Creek Region: Cook Inlet Location: Section 22 T2S R 13W, SM Coordinates: 1104' FSL,1300' FEL Elevation: Rig floor elevation = 748.9' AMSL GL= 732.5' AMSL County, State: Kenai Peninsula Borough, Alaska API Index: 50-231200-21-00 · Spud Date: September 13th , 2004 Total Depth: 8478' Contractor: Nabors Drilling Alaska Company Representative: Donnie Fowler RiglType: Nabors #129/ Land Epoch Logging Unit: #30 Epoch Personal: Lees F. Browne Jr. Sergi Pokrovsky Company Geologist: Mark Lynch · ~ El)()C·H 3 . . . UNOCALe Happy Valley #9 Casing Data: 13 3/8" landed at 56' 7" at 3293' Hole size: 8.5" to 3300' 6 1/8" to 8478' Mud Type: Spud to 1074' LSND to 8478' Logged Interval: Full Logging under surface casing @ 3300' Gas Log from conductor to surface casing Reeves Electric Logging Co: Logs Run: Single Quad Combo ~ El)()CH 4 · · · UNOCALe Happy Valley #9 PROCEDURES AND GENERAL DISCUSSION Epoch supplied a full computerized Rigwatch 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 (F/D) 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 #9 on September 13th, 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 57'. Commenced logging with rop/gas log in 8.5" surface hole and was drilled with water base spud mud from surface' to 1074' in which lost circulation forced the mud to be swapped over to LSND mud and completed on September 15th, 2004. The rig lost circulation for 15 minutes at 1026' with a loss of 45 bb/s. Lost circulation again at 1067' to 1074' for 12 minutes and lost 50 bbls of mud to the formation. Mud weight was 9.3 ppg and decreased to 8.7+ and increased again to 9.2 while drilling the "lower" surface interval with a carbide dropped at 3300' which showed "no" returns on the carbide (most likely lost to the formation through partial lost circulation). Casing was run to bottom with lost returns at 1100 strokes. The surface hole section was drilled with a total loss of mud of 693 bb/s. Normal sliding was needed after the kick off point of 250' to maintain the target angle of 3.5 degrees per 100' to a total of 49 degrees at 1800'. Cuttings collection and analysis commenced from under surface casing and began on September 18th, 2004. Cuttings samples were caught at 30' intervals and at smaller intervals if the drill rate allowed during high gas intervals to 8478'. 10' spot samples where caught depending on the rate of penetration. The intermediate 6 1/8th hole section was drilled with water base mud from 3330' to 8478'. A slight amount of sliding was necessary to keep and maintain a target tangent angle of approximately 49«' to 3784', in which, the target was dropped 2° per 100' to 18.48 degrees at 8478'. Holding the angle became very hard from 4300' to 4700'. The BHA was tripped out and changed because of the ghost reamer being out ofthe shoe. A shorter BHA was run and a 2° drop per 100' was maintained. Mud weight was gradually increased from 9.0+ to 9.5 ppg. Connection gases were noted after 6674' and averaged 5-10 units over background. Intermediate hole was completed on September 22th, 2004, with a carbide drop showing a 24.5 bbl wash out over a gauged hole and casing run to bottom with no problems. Down hole electric wireline data was obtained by a Reeves Quad-Combo Assembly. 3%" production tubing was run in the hole on 4" drill pipe, the hanger set, and the tubing string cemented on September 24th, 2004 Epoch was given its release to rig down after cementing. [~ El)()C·H 5 UNOCALe Happy Valley #9 · GEOLOGICAL DISCUSSION Happy Valley #9 The primary objectives of Happy Valley #9 were quality Tyonek Formation gas sands. The 61/8" hole was drilled from 3300' to a total depth of 8478', included Lower Beluga and Tyonek Formations. Gas averaged 76 units, with a maximum of 774 units (best show): Sand and sandstone at 8215' to 8240'. The rate of penetration increased from 60 f/h to an average of 150 f/h and slowing down in the basal section to 80 fIr. Gas units 60 increasing to 774 max to 60. Lithology for this zone: (8215' to 8240') Sand/Sandstone = very light gray to light gray, clast size ranges from medium lower to very fine lower, sub rounded to angular, moderate to well developed sphericity, poorly sorted in a silty occasionally ashy matrix, mostly matrix supported with moderate to slight grain contact, polished texture with slight pitting, composed of 80-90% quartz and 10-20% carbonaceous lithics and silicates, poor to fair visible porosity, fairly clean sand, no oil indicators. Other sand / sandstone show zones occurred at the followino deoths with oases and ROP listed: Show #1 from 5960' to 5980' (20') gas: 25 units to 173 max to 35 units. ROP 155 to 200+ to 170 ft/hr 70% Sand: medium light gray, clast size ranges from medium grains to very fine, sub round, moderate to well developed sphericity; poor sorting; polished texture, sub mature nature, no visible silic cement; moderate to dominant clay matrix; both matrix and grain support; very hydrophilic clays; composed of quartz and dark gray metalithics; poor to fair porosity and permeability; no oil indicators. · Show #2 from 6375' to 6390' (15') gas: 140 units to 318 max to 70 units. ROP 120 to 155 to 120 ft/hr 40-60% Sand: light gray; clast size ranges from medium lower to fine lower; sub round; moderate to well developed sphericity; moderate sorting; chipped to impacted texture; sub mature; no visible cement; dominant clay structured matrix; matrix supported with some secondary grain support; composed of 50% quartz, 50% dark gray metalithics, chert and various lithic fragments; poor porosity and permeability; no oil indicators. Show #3 from 6715' to 6770' (55') gas: 180 units to 290 units to 50 units. ROP 200+ ft/hr 40-60% Sand: very light gray to light gray to salt & pepper appearance; clast size ranges from medium lower to very fine upper; sub round to sub angular; mostly sub rounded; moderate developed sphericity; very poor sorting; sub mature nature; non to slight silic cement; moderate clay/silt structured matrix; clay supported with some grain support in minor parts; composed of 50% quartz, 40% dark gray metalithics, 10% chert; poor to fair porosity; poor permeability; silty-dirty appearance. Show #4 from 7155' to 7175' (20') gas: 18 units to 211 units to 57 units. ROP 160 to 180 to 200+ ft/hr 40% Sand, 30% Sandstone: very light gray to medium light gray; clast size ranges from medium lower to very fine upper; occasionally scattered coarse grains; sub angular to sub round; moderate developed sphericity; both matrix and grain supported in ashy/clay with slight very fine sand and tuffaceous silt matrix; composed of 80% quartz, 20% black to gray silicates; poorly sorted; poor to some fair visible porosity; no oil indicators. · Show #5 from 7435' to 7455' (20') gas: 27 units to 359 units to 200 units. ROP 80 to 120 to 80 ft/hr 80% Sand: medium light gray; clast size ranges from medium upper to very fine; sub angular to sub round; moderate developed sphericity; poor sorting; chipped to pitted texture; sub mature; no visible cement; moderate silt structured matrix; grain supported with secondary matrix support; appears silty and dirty; composed of 60% quartz, 30% dark gray metalithics, 10% chert; fair porosity and permeability; no oil indicators. Show #6 from 7517' to 7590' (73') gas: 150 units to 277 units to 90 units. ROP 85 to 140 to 100 ft/hr ~ EI)()C·H 6 UNOCALe Happy Valley #9 · 30-40% Sand: light gray; clast size ranges from fine upper to silt; sub round to rounded; moderate to well developed sphericity; poor sorting; polished to pitted texture; sub mature nature; non to very slight silic cement; large silt/clay structured matrix; matrix supported with secondary grain support; composed of >90% quartz; poor with some fair porosity; poor permeability; no oil indicators. Show #7 from 7690' to 7715' (25') gas: 17 units to 356 units to 30 units. ROP 100 to 150 to 110 ftIhr 70-80% Sand: medium light gray; clast size ranges from medium upper to very fine; sub round; moderate sphericity; poor sorting; chipped to impacted texture; sub mature; no silic cement; slight to moderate clay/ash matrix; very hydrophilic; grain support with secondary matrix support; composed of >90% quartz; fair porosity and permeability; no oil indicators. Show #8 from 7775' to 7805' (30') gas: 100 units to 464 units to 35 units. ROP 125 to 115 to 80 ftIhr 60-70% Sand: medium light gray; clast size ranges from medium upper to fine lower; sub round; moderate developed sphericity; becoming moderately sorted at 7790'; moderate silt/clay matrix; mostly matrix supported; with some grain support in parts; composed of 70% quartz, 20% metalithics, 10% chert; poor to fair porosity and permeability; no oil indicators. Coal beds just above show zone. Show #9 from 7850' to 7900' (50') gas: 90 units to 454 units to 65 units. ROP 40 to 80 to 60 ftIhr 50-100% Sand: very light gray; clast size ranges from medium lower to very fine upper; sub round; moderate to well developed sphericity; moderate sorting; polished to chipped to impacted texture; sub mature nature; non to weak silic cement; slight to moderate clay matrix; dominant grain support with secondary matrix support: loosely attached at 7880'; composed of 90% quartz; fair to good porosity and permeability; fairly clean sand; no oil indicators. · Show #10 from 8405' to 8445' (40') gas: 50 units to 576 units to 45 units. ROP 40 to 190 to 90 ftlhr 40 -70% Sand, 20% Sandstone: very light gray to light gray; clast size ranges from coarse lower to very fine upper; occasionally scattered very coarse grains of light brown to pale yellowish orange quartz; sub rounded to angular; moderate to well developed sphericity; overall matrix supported with slight to moderate grain contact; grading to ash, silt and some clay; composed of 75% quartz, 25% gray to brown to minor pink to tan silicate grains; occasionally some minor calcite clasts; poor to fair porosity; no oil indicators; DAILY ACTIVITY SUMMARY (Note: All daily summaries reported at 24:00:00 of listed date.) 9/13/04 Rig up Happy Valley #9 9/14/04 Install mouse hole and picked up bales and hang rig tongs. Picked up test joint and rig up and test BOPE. Flange leaked on the Hydrill = tighten and retested. Lay down test equipment and install wear ring. Picked up 4" HWDP and stood back in the derrick. Picked up BHA and drilled to 227'. Stand back HWDP and pick up MWD and flex collars. Drill formation. 9/15/04 Drill to 908' and pulled out of the hole to the collars. Pick up 5" HWDP and drill to 1074'. Hole is losing fluid and the well was observed. Pulled two stands and mixed LCM pill and ran into the hole. Pumped a pill and mixed and pumped a second LCM pill. Pulled two stands and started to build pit volume. Observed the well and taking 10 bbllhr static. Control drill formation. · 9/16/04 Drill formation to 3300' and circulated the hole clean. Pumped a carbide and walnut sweep with "no" returns. Pump out of the hole to 2950'. Hole is tight and back ream out. The hole is giving back mud on [:I El)()CH 7 · · · UNOCALe Happy Valley #9 connections. Back ream out of the hole to 700' and monitor the well. Hole gave back 60 bbls. Continue to pull out of the hole. 9/17/04 Lay down 5" HWDP with the BHA and clear the rig floor. Pull wear ring and make dummy run with hanger. Rig up and run 7" casing to bottom with no problems. Pick up hanger and landing joint and circulate bottoms up two times. Rig up cement head and test lines to 3000 psi. Cement the hole and lost returns at 1100 strokes into displacement. Bump the plug and test the casing for thirty minutes. Well flowing back on the back side. Rigged up gauge = 28 psi. Rig up cementers and pumped 43 bbls of 15.8 ppg cement. Circulate out lower pipe rams to 4" and rigged up and tested the BOPE. 9/18/04 Continue to test BOPE and lay down test joint. Installed the wear bushing and cemented the top job (4-5 bbls). Run in the hole with gyro and pull out of the hole and rig down. Rig up e-line and run in the hole and perform cement bond log. Rig down e-line and service the draw works. Pick up BHA and run in the hole with HWDP from the derrick. Test MWD and pick up drill pipe and stand back in the derrick. 9/19/04 Run in the hole to bottom and repair the top drive. Break circulation and tag cement at 3240'. Hold a pre job safety meeting and a choke drill was conducted. Drilled out the cement and float equipment. Drilled to 3320' and rigged up Schlumberger to perform the FIT test. Sclumberger won't pump and thety are rigged down. Rig up rig test pump and perform the FIT to 14.2 ppg EMW. Drill formation to 3371' and trip out of the hole for MWD failure. Circulate bottoms up and pump a dry job. Changed out thwe MWD and orientate the tool. Run in the hole and drill formation. 9/20/04 Drill formation to 4733', in which difficulty trying to slide prevented any further drilling. Circulated bottoms up and monitored the well. Pull out of the hole and changed the BHA. Had to back ream from 4032' to 3843' while pulling out of the hole and then changed the BHA and tripped back into the hole. 9/21/04 Drill formation to 5697' and circulate bottoms up. Pull a wiper trip to the deepest ghost reamer and run in the hole. Wiper gas was 24 units over back ground gas and drill ahead. 9/22/04 Drill formation to 6643' and circulate a sweep around the hole. Short trip the bit to 5633' with a few tight spots, but no pumping was needed and run in the hole and circulate up 180 units of wiper gas. Drill ahead with connection gases noted (average 15 units) at each connection afterward. 9/23/04 Drilled to 7590' and pumped a sweep and short tripped to 6570'. Tripped in the hole and had 212 units of wiper gas. Drilled to 8478' (TD) and short tripped to 4116' and ran in the hole to TD and circulated out 506 units of wiper gas. 9/24/03 Pulled out of the hole and ran 3.5" tubing to TD and cemented. [:I El)()C·H 8 · · · UNOCALe Happy Valley #9 LITHOLOGY REVIEW Commence logging Happy Valley #9 at 16:31 on 9/13/04 at surface with gas log to 3300' Commence sample log on 9/18/04 Sand (3330' to 3380') = medium gray to light gray; coarse to fine grain; moderate sphericity; poor sorted; polished texture; sub mature; no visible matrix; dominant matrix support; composed of quartz with fair to good porosity and permeability; no oil indicators. Tuffaceous claystone/tuffaceous siltstone (3390'-36301 = very light grey; very soft to soft; very hydrophilic; lumpy to clumpy; mushy to pasty; moderate adhesive; amorphous to earthy fracture; clayey to colloidal texture; composed of 80% clay and 20% silt and very fine amount of carbonaceous material. Tuffaceous claystone/tuffaceous siltstone (3630' - 3690') = very light grey; very soft to soft; predominantly lumpy to clumpy; clustered to clotted; very hydrophilic; slightly adhesive; slightly cohesive; amorphous to sub nodular habit; massive beds of homogeneous clay; most going into drilling mud; composed of 70- 80% clay and 20-30% silt, very fine amounts of carbonaceous material. Coal/carbonaceous shale (3400' - 36001 = black to grayish black; firm; earthy luster; smooth to matte texture; splintery to irregular fracture; elongate to tabular habit; composed of lignitic coal to very carbonaceous shale at contacts; becoming silty in part. Sand/sandstone (3390'-3530') = medium light grey to medium grey; overall color derived from supporting tuffaceous clay; upper fine to lower coarse; poor to moderate poor sorting overall; subangular to subrounded; moderate sphericity; poor to moderate sorted; polished to impacted texture; non calcareous; clay structured matrix; roughly 40 to 50% quartz. Tuffaceous claystone / tuffaceous siltstone (3690' - 3750') = light grey to medium light grey; very soft to soft lumpy to clumpy; gelatin mushy to pasty; tacky to slimy; various consistent; very hydrophilic; amorphous to sub nodular habit; moderate earthy luster; clayey to colloidal texture; massive bed of homogeneous clay composed of 80% clay, 20 % silt; scattered very fine carbonaceous material and coal. Coal/ carbonaceous shale (3740' -3800') = black to brownish black to very dusky brown; coal is brittle to firm; and fragile to moderately tough; carbonaceous shale is slight to moderately firm; most coal has irregular sub platy habit, and irregular fracture some higher grade lignite has a blockier habit and irregular to sub-conchoidal fracture; most coal and abundant carbonaceous shale has a dense matte texture and dull luster. Tuffaceous clay / tuffaceous siltstone (3750' - 3830') = light gray -grey to light grey; very soft to soft; lumpy to clumpy; clotted to clustered; mushy to pasty; very adhesive; amorphous to earthy habit; moderately earthy luster; clayey to colloidal texture; massive bed of homogeneous clay; composed of 80- 90% of clay and 10-20% of silt, also particles and sand-size clastic grains of coal and carbonaceous shale. Tuffaceous claystone (3840' to 3930') = light gray to very light gray; very soft to brittle; very hydrophilic; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; non cohesive to non adhesive; amorphous fracture and habit; colloidal in most consistencies; earthy luster; ashy to colloidal texture; massive beds of homogeneous tuffaceous claystone; composed of 80% clay and 20% silt; some scattered thin to thick very carbonaceous shale grading to lignitic coal. ~ El)()C·H 9 UNOCALe Happy Valley #9 · Coal/very carbonaceous shale (3900' to 3915') = black to grayish black; firm; earthy to resinous luster in coal beds; matte texture; planar fracture along shale partings to hackly to sub blocky in coal; slight visible bleeding gas in coal sections. Sand (3950' to 39751 = very light gray; clast size ranges from medium upper to silt; sub round; moderate to well developed sphericity; very poor sorting; polished to impacted texture; immature; no visible cement; abundant matrix clay; dominant matrix support; sands appear as interbedded grains to very minor beds; poor porosity to very poor permeability; no oil indicators. Tuffaceous claystone (3980' to 4020') = medium light gray; very soft; brittle; lumpy to clumpy; clustered to clotted; amorphous fracture and habit; moderate earthy luster; colloidal texture; massive beds of homogeneous clay with gradational beds of very carbonaceous shale and clay. Coal/carbonaceous shale (4020' to 4035')= grayish black to brownish black some becoming black; brittle to firm; most cuttings very ground up; earthy luster; matte texture; planar fracture along shale partings grading into hackly in coal sections; composed of very carbon shale with thin beds of lignitic coal; very slight visible bleeding gas. Tuffaceous claystone (4040' to 4130') = medium light gray; very soft; brittle; lumpy to clumpy; clustered to clotted; amorphous fracture to amorphous habit; moderate earthy luster; colloidal text; massive beds of homogeneous tuffaceous claystone; very hydrophilic; thin lams of very carbonaceous clay and shale. Sand (4140' to 4200') = medium light gray; clast size ranges from medium upper to silt; sub round to rounded; moderate some well developed sphericity; very poor sorting; polished texture; immature nature; no visible cement; dominant clay matrix and support; sand appears as interbedded sands; poor porosity and permeability; no oil indicators. · Tuffaceous claystone (4210' to 4260') = medium light gray to light gray; very soft to brittle; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; various consistencies; non cohesive to non to very slight adhesive; very hydrophilic; amorphous fracture; amorphous habit; moderate earthy luster; colloidal texture; composed of massive beds of homogeneous beds of tuffaceous claystone; composed of 80% clay, 20% silt and various detrital material; scattered thin laminae of very carbonaceous material. Carbonaceous shale (4270' to 4320') = black mottled grayish brown to dusky brown; brittle to firm; earthy luster in carbon shale to sub resinous in coals; matte to gritty texture; planar fracture to flakey fracture along shale partings grading to hackly in coal cuttings; composed of very carbonaceous shale and clay grading to sub lignitic coal in very thin laminae to thin beds; slight visible bleeding gas in cuttings. Sand (43230' to 4380') = very light gray clast size ranges from medium lower to silt; sub round; moderate sphericity; very poor sorting; polished to impacted texture; immature nature; no visible cement; abundant clay matrix and matrix support; composed of 90% quartz, 10% meta and various lithic fragments; poor porosity and permeability; occurring as interbedded loose sands to thin beds; no oil indicators. Tuffaceous claystone (4390' to 4460') = medium light gray to light gray; very soft; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; non cohesive to very slightly adhesive; amorphous fracture and habit; very hydrophilic; moderate earthy luster; colloidal texture; massive beds of homogeneous tuffaceous claystone; composed of 90% clay 10% various lithic fragments. Sand (4470 to 4480') = very light gray; clast size from fine to silt; sub round; moderate sphericity; very poor sorting; polished to impacted texture; immature nature; no visible cement; dominant clay structured matrix and support; appears as loose sands mostly interbedded in clays; poor porosity and permeability; no oil indicators. · Tuffaceous claystone (4490' to 4530') = medium light gray; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; slimy in parts; non cohesive to non to slight adhesive; amorphous ~ El)()CH 10 UNOCALe Happy Valley #9 . fracture and habit; moderate earthy luster; colloidal texture; very hydrophilic; massive homogeneous beds of clay; composed of 90% clay, 10% silt. Tuffaceous claystone I tuffaceous siltstone (4530' - 4650') = light gray to medium gray; slightly finn; planer to irregular fracture; clayey to silty to very fine sandy texture; soluble to moderately soluble; mushy to pasty; some grading siltstone and sandstone; some scattered carbonaceous flakes to rare dark. gray to grayish brown grading carbonaceous shale. Sand I sandstone (4550' - 4650') = very light gray to medium light gray; very fine to fine and locally scattered medium to coarse lower; subangular to subrounded; moderately to poor sorted mostly grain supported; moderately well consolidated with slight clay matrix; 60-70% quartz; poor to fair porosity. Tuffaceous siltstone I tuffaceous claystone (4600' - 4700') = medium gray to medium light gray; moderate induration; crumbly to crunchy; moderate cohesive to non adhesive; granular fracture and habit; moderate earthy luster; very silty to gritty texture; some grading to very fine grain sandstone in parts; composed of 50-60% silt, 40-50% clay, most of clay is washed out; some various detrital material and very fine sand. Sand (4710' to 48001 = light gray; clast size ranges from medium upper to fine lower; moderate sphericity; moderate sorting; pitted texture; immature; no visible cement; dominant clay matrix becoming less with depth; matrix supported at 4770' becoming grain supported at 4890'; composed of >90% quartz, poor porosity and penneability becoming poor to fair with depth. Sand (4810' to 4860') medium light gray; clast size range medium upper to very fine upper; sub round to rounded; moderate to well developed sphericity; poor sorting; polished to impacted text; sub mature nature; no visible cement; dominant clay matrix; matrix with some grain support; composed of >90% quartz, poor to fair porosity and penneability; no oil indicators. . Sand (4870' to 4920') = medium gray to medium dark. gray; clast size ranges from coarse lower to fine lower; sub angular to sub round; moderate sphericity; very poor sorting; pitted to impacted texture sub mature nature; slight to moderate clay matrix; both grain and matrix support; composed of 50% quartz, 50% dark. gray metalithics and various lithic fragments; poor to fair porosity and penneability; no oil indicators. Sand (4930' to 4980') = medium dark. gray clast size ranges from coarse lower to fine lower; sub angular coarser to sub round finer grains; moderate to well developed sphericity; poor sorting; pitted texture; sub mature nature; no visible cement; slight clay matrix; dominant grain support; appears silty; composed of 60% quartz, 40% metalithics and various lithic fragments; fair porosity and penneability; no oil indicators. Tuffaceous claystone (4990' to 50401 = light gray; very soft; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty; tacky to slimy; non cohesive to slight adhesiveness; amorphous to earthy fracture; massive to amorphous habit; moderate earthy luster; clayey to colloidal texture; massive beds of hydrophilic clay; visible pyro-clastic relic shards in silty sections. Carbonaceous shale (5050' to 51001 = black mottled brownish black to dusky brown; brittle to finn; overall earthy luster with minor resinous laminae; matte to gritty texture; planar fracture along shale partings; composed of very carbonaceous shale with minor laminae of sub lignitic coal. Carbonaceous shale (5110' to 5130') = black mottled grayish black; brittle; earthy luster; matte to gritty texture; planar fracture along shale partings; cuttings are very small being subjected to the mud motor and PDC bit; composed of very carbonaceous shale; no visible bleeding gas. Sand (5140' to 5200') = medium gray; clast size ranges from medium upper to very fine upper; sub round; moderate to well developed sphericity; moderate to poor sorting; polished to chip texture; sub mature; no visible cement; moderate clay matrix with both grain and matrix support; composed of quartz and . metalithic fragments; fair porosity and penneability; no oil indicators. [:I El)()C·H 11 . . . UNOCALe Happy Valley #9 Sand (5210' to 5250') = medium light gray; clast size range coarse lower to very fine; sub round; moderate to well developed sphericity; very poor sorted; polished texture; sub mature; no visible cement; moderate clay matrix; both grain with secondary matrix support increasing with depth; composed of 50% quartz, 40% dark gray metalithics, 10% chert; poor to fair porosity and penneability; no oil indicators. Sand (5270' to 5310') = medium gray; clast size range coarse lower to fine lower; sub round; moderate sphericity; poor sorting; polish to chip texture; sub mature; non to very slight silicate cement; moderate clay matrix; both grain and matrix support with matrix increases with depth; composed of 60% quartz, 30% metalithics, 10% chert and various lithic fragments; fair to poor porosity and penneability; no oil indicators. Sand (5320' to 5345') = medium dark gray clast size medium lower to fine lower; sub round; moderate sphericity; moderate to poor sorting; pitted texture; sub mature; non to very slight silicate cement; moderate clay structured matrix; both grain and matrix support; composed of 50% quartz, 40% dark gray metalithics, 10% chert; fair to poor porosity and penneability; no oil indicators. Carbonaceous shale (5350' to 5390') = brownish black mottled grayish black; black; brittle to finn; earthy luster; matte to gritty texture; sub planar to sub blocky fracture; composed of very carbonaceous shale grading to lignitic coal; visible bleeding gas from cuttings. Tuffaceous claystone (5400' to 5430') = medium light gray to light gray; very soft; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky to slimy; slightly cohesive; slight to moderate adhesive; earthy to amorphous fracture; massive clay beds. Coal/carbonaceous shale (5470'-5520') = brownish black to dusky brown to grayish black; slightly finn and crumbly to very finn and brittle; hackly to flaky fracture; dull polish to slightly shiny luster; lignite often with clay residue on partings; inter1aminated with to grading carbonaceous shale with thin carbonaceous partings in brownish organic claystone; some degassing on fractures. Sand (5500' to 5580') = medium dark gray clast size medium lower to fine lower; sub round; moderate sphericity; moderate to poor sorting; pitted texture; sub mature; non to very slight silicate cement; moderate clay structured matrix; both grain and matrix support; composed of 40% quartz, 40% dark gray metalithics, 20% chert; fair to poor porosity and penneability; no oil indicators. Tuffaceous claystone / tuffaceous siltstone (5500'- 5610') = medium light gray; soft; clayey to siltylfine sandy texture; moderately soluble; slightly adhesive; amorphous to earthy fracture; massive to amorphous habit; moderate earthy luster; clayey to silty texture; slight carbonaceous laminations and flakes. Sand (5580' to 5670') = medium light gray; clast size range coarse lower to very fine; sub round; moderate to well developed sphericity; very poor sorted; polished texture; sub mature; very clayey as mostly matrix supported; 50-60% quartz and 40% mostly black to dark brown carbonaceous and some silicate fines, flakes and silts, poorly consolidated with soluble matrix; poor to fair porosity. Sand (5700') = very light gray; clast size very fine upper to medium lower; well to moderate sorted; rounded to subrounded; polished texture; 70%-80% quartz, 20%-30% mostly black sometimes brownish carbonaceous and silicate flakes and silts; clay structured matrix; poor visible porosity. Tuffaceous claystone (5670' - 5790') = medium light gray to occasionally light brownish gray; moderately soft to slightly finn; slightly to moderately silty/gritty texture; very slight to occasionally moderate disseminated silt sand fines; occasionally grading brownish gray to dusky brown organic claystone with common carbonaceous flakes and partings and thin coals; grading siltstone to fine sandstone; mostly matrix supported with quartz grains, carbonaceous fines and flakes, dark silicates; visible outgassing from coals. [;1 El)()C·H 12 UNOCALe Happy Valley #9 · Tuffaceous claystone I tuffaceous siltstone (5790' - 5880') = light gray to medium light gray; slightly firm to soft; moderately soluble; smooth to silty texture; locally sandy including very fine to fine grains; massive to locally interbedded to interlaminated with siltstone; non calcareous; composed of 80% clay and 20% silt. Sand (5850' - 5900') = medium light gray silt to very fine grains; occasionally medium grains; subangular to subrounded; moderately to occasionally poorly sorted; grading to siltstone and claystone; matrix and grain supported in silty clay matrix; 50% quartz and 50% black to dark gray grains including mostly carbonaceous silts and fines; very poor visible porosity. Tuffaceous claystone I tuffaceous siltstone (5880' - 5950') = medium light gray to medium gray; slightly firm; moderately soluble; smooth to silty texture; sandy including very fine to fine grains; some with slight carbonaceous fines and flakes; composed 50% clay, 40% silt, 10% various lithic fragments. Sand (5960' - 5980') = medium light gray clast size medium to very fine; sub round; moderate to well developed sphericity; poor sorting; polished text; sub mature; no visible cement; moderate to dominant clay matrix; both matrix and grain support; very hydrophilic clays; composed of quartz and dark gray meta- lithics; poor to fair porosity and permeability; no oil indicators. Carbonaceous shale and coal (5990' to 6080') = black. to grayish black some mottled reddish black; brittle to firm; earthy to resinous luster in coal; matte to gritty some smooth texture in coal; planar fracture along shale partings to hackly in coals; visible bleeding gas in coal cuttings. Sand (6090' t06120') = medium light gray clast size medium lower to very fine; sub round; moderate to well developed sphericity; poor sorting; pitted texture sub mature; non silicate cement; abundant clay structure matrix with some grain support; composed of >90% quartz; poor some fair porosity and permeability; no oil indicators. · Carbonaceous shale and coal(6125' to 6135') = black mottled brownish black; brittle to firm; earthy to resinous luster; matte to smooth some gritty text planar to hackly fracture; composed of very carbon shale grading to lignitic coal; some bleeding gas; small cuttings. Coal carbonaceous shale (6130' to 6220)black some mottled brownish black; brittle to firm; resinous some earthy luster in carbon shale; smooth to matte texture; planar to hackly fractures; composed of lignitic coal to very carbonaceous shale at contacts; visible bleeding gas; cuttings are very small in size = ground up by mud motor. Tuffaceous claystone (6230' to 6270) = medium light gray; very soft; malleable to sectile; flexi to elastic; lumpy to clumpy; clustered to clotted; mushy to pasty; slight cohesiveness to very adhesive; amorphous to earthy fracture; massive habit; moderate earthy luster; clayey texture; gradational beds of clay and thin beds of carbonaceous shale grading to coals; composed of 70% clay, 20% carbon, 10% silt and various detrital material. Carbonaceous shale (6280' to 6370') = black. to grayish black; brownish black in parts; brittle to firm; dominant earthy luster; smooth to gritty texture; planar fracture along shale partings; composed of thin beds of very carbon shale and clay. Sand (6380' to 6400') = light gray; clast size range medium lower to fine lower; sub round; moderate to well developed sphericity; moderate sorted; chip to impacted texture; sub mature; no visible cement; dominant clay structured matrix; matrix supported with some secondary grain support; composed of 50% quartz, 50% dark gray metalithics, chert and various lithic fragments; poor porosity and permeability; no oil indicators. · Carbonaceous shale (6410' to 6420') = black. to grayish black mottled reddish brown; brittle to firm; earthy some resinous luster; gritty to matte text; planar fracture along shale partings; composed of thin to laminae beds of very carbonaceous shale; slight visible bleeding gas from some fragments; all very small ground up appearance. [:I El)()CH 13 UNOCALe Happy Valley #9 · Tuffaceous claystone (6430' to 6480') = medium light gray; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty; tacky to slimy; slight cohesive; moderate adhesive; amorphous to earthy fracture; massive habit; moderate earthy luster; clayey to colloidal texture; hydrophilic; interbedded medium to fine grained sands; massive beds of silt, sand and clay. Tuffaceous claystone (6490' to 6540') = medium light gray; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty; tacky to slimy; slight cohesive; moderate to very adhesive; amorphous to earthy fracture; massive habit; moderate earthy luster; clayey to colloidal texture; hydrophilic; thin to laminae of very carbonaceous shale. Carbonaceous shale (6550' to 6620') = black mottled brownish black; brittle to firm; earthy luster; matte to gritty texture; planar fracture along shale partings; slight visible bleeding gas. Sand (6630' to 6650') = very light gray to light gray; clast size ranges from medium upper to very fine lower; sub round; moderate to well developed sphericity; very poor sorting; pitted to impacted texture; sub mature nature; no to slight silicate cement; moderate some abundant clay/silt structured matrix; dominant clay structured support with secondary grain support in parts; composed of 60% quartz, 30% dark gray metalithics, 10% chert; poor to fair porosity; poor permeability; no oil indicators; appears detrital rich and silty dirty appearance. Tuffaceous claystone / tuffaceous siltstone (6650'-6690') = medium gray to medium light gray; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty; tacky to slimy; slight cohesive; moderate to very adhesive; amorphous to earthy fracture; massive habit; moderate earthy luster; clayey to colloidal texture; hydrophilic; thin to laminae of very carbonaceous shale. · Coal/carbonaceous shale (6790'-67051 = black to brownish black; brittle to firm; smooth to matte texture; earthy to resinous luster; composed of lignitic coal to very carbonaceous shale at contacts; visible outgassing; very small cuttings = ground by mud motor. Sand (6720' - 6770') = very light gray to light gray to salt and pepper; grain size ranges from very fine upper to medium lower; sub round to subangular; mostly sub rounded; moderate developed sphericity; very poor sorting; sub mature nature; no to slight silicate cement moderate clay/silt structured matrix; clay structured support with grain support in parts; 50% quartz, 40% dark gray metalithics, 10% chert, poor to fair porosity; poor permeability; silty dirty appearance. Tuffaceous claystone (6490' to 6540') = medium light gray; very soft; lumpy to clumpy; clustered to clotted; mushy to pasty; tacky to slimy; slight cohesive; moderate to very adhesive; amorphous to earthy fracture; massive habit; moderate earthy luster; clayey to colloidal texture; hydrophilic; interbedded with silt. Coal/carbonaceous shale (6865' - 6890') black to grayish black to brownish black firm; resinous to some earthy luster at carbonaceous shale contacts; matte texture; hackly to granular fracture; composed of /ignitic coal to sub bituminous grading to very carbonaceous shale. Sand/sandstone (6895' - 6930') = light gray to medium gray; clast size ranges medium lower to very fine lower; sub round to rounded; moderate to well developed sphericity; poorly sorted; polished to pitted texture; sub mature; slightly cemented; abundant silt/clay matrix; hard to discern between siltstone and sandstone with matrix; composed of 60-70% quartz, 30-40% various lithic fragments; poor porosity; poor permeability. Tuffaceous siltstone (6980' - 7050') = brownish gray; moderate induration; crunchy; stiff; mushy to pasty when rehydrated; moderate cohesiveness to not adhesive; silty to gritty texture; moderate earthy luster; massive beds of homogeneous silt composed of 70-80% of silt, 20-30% of clay and various detrital · material; locally grading dusky brown carbonaceous shale. [:I El)()C·H 14 UNOCALe Happy Valley #9 · Tuffaceous siltstone (7050' - 7100') = medium light gray to medium gray to brownish gray; poor to moderate induration; mushy to pasty when rehydrated; crumbly to crunchy; stiff; moderate earthy to dull earthy luster; silty to gritty texture; massive beds of homogeneous tuffaceous silt composed of 80% silt, 20% tuffaceous clay and various detrital material. Sand (7070' - 7140') = medium light gray to light gray; very fine lower to fine lower; subangular to subrounded; moderate sphericity; poorly to moderately sorted; matrix and grain supported; interbedded with tuffaceous claystone and siltstone; 70% quartz, 30%black to gray to brown silicates and carbonaceous lithics; some alterations of lithics to clay; poor porosity; poor permeability. Sandstone (7150' - 7180') = very light gray to medium light gray; very fine upper to medium lower, occasionally scattered coarse grains; subangular to subrounded; moderately high sphericity; matrix and grain supported in ashy clay with slight sandy tuffaceous siltstone; 80% quartz, 20% black to gray silicates; poorly sorted; poor to some fair visible porosity. Coal/carbonaceous shale (7190'-72101 = black to grayish black to brownish black very firm and brittle; hackly to platy fracture; resinous luster; matte texture composed of lignitic to bituminous coal grading to carbonaceous shale; coal is very ground up with bit; abundant visible bleeding gas from coal and shale tuffaceous claystone / tuffaceous siltstone (7230' - 7290') = medium light gray to medium gray; slightly firm to medium firm; soluble and slightly expansive in water; mostly slightly silty/gritty texture; lightly speckled to scattered carbonaceous matter. Coal (7260' - 72701 = black to brownish black; very firm and brittle with hackly to platy fracture, to moderately firm and crumbly; subbituminous to lignite and grading to carbonaceous shale with increase in organic clay. · Tuffaceous claystone (7290' - 73501 = light gray; slightly firm to moderately soft; smooth to some silty texture; soluble; some slight carbonaceous matter some grading siltstone to matrix supported sandstone; often scattered flakes of carbonaceous material. Sand/sandstone (7340' - 7380') = light gray; very fine upper to occasionally medium lower; subangular to subrounded moderate to well developed sphericity; polished to pitted texture; abundant silt/clay matrix. Sand (7435' to 7460') = medium light gray; clast size ranges from medium upper to very fine grains; sub angular to sub round; moderate developed sphericity; poor sorting; chip to pitted texture; sub mature; no visible cement; moderate silt structured matrix; grain supported with secondary matrix support; appears silty and dirty; composed of 60% quartz, 30% dark gray metalithics, 10% chert; fair porosity and permeability; no oil indicators. Coal carbonaceous shale (7465' to 74751black to grayish black mottled light grayish brown to brown in parts; firm; earthy to resinous luster; planar to sub blocky fracture; slight visible gas bleeds from coals. Sand (7480' to 75601 = light gray; clast size ranges from fine upper to silt; sub round to rounded; moderate to well developed sphericity; poor sorting; polished to pitted texture; sub mature; non to very slight silicate cement; large silt/clay structured matrix; matrix supported with secondary grain support; composed of >90% quartz; poor some fair porosity; poor permeability; no oil. Tuffaceous siltstone (7570' to 76501 = medium gray; poor induration; brittle; slight cohesive; non adhesive; earthy fracture; platy to tabular habit; dull earthy luster; silty to gritty texture; gradational beds of silt and clay with scattered thin sands; composed of 70% silt, 30% clay and various detrital material. · Sand 7660' to 7685') medium light gray; clast size range medium upper to very fine upper; sub round to rounded; moderate to well developed sphericity; poor sorting; polished to impacted text; sub mature; no visible silicate cement; large clay/silt matrix with dominant matrix support and secondary grain support; becoming grain supported at 7685' and much cleaner sand; composed of >90% quartz; poor to fair @ 7685' porosity and permeability; no oil indicators. [:I El)()C·H 15 UNOCALe Happy Valley #9 · Sand (7690' to 7715) = medium light gray; clast size range medium upper to very fine; sub round; moderate sphericity; poor sorting; chip to impact texture; sub mature; no silicate cement; slight to moderate clay/ash matrix; very hydrophilic; grain support with matrix support secondary; composed of >90% quartz; fair porosity and permeability; no oil indicators. Coal carbon shale (7720' to 7770') = black mottled brownish black; brittle to firm; earthy to resinous luster; gritty to matte texture; planar to flakey fracture along shale partings to hackly coal; composed of carbon shalellignite. Sand (7775' to 7805') = medium light gray; clast size medium upper to fine lower; sub round; moderate sphericity; becoming moderate sorting @ 7790'; moderate silt/clay matrix; mostly matrix supported with some grain support; composed of 70% quartz, 20% metalithics,1 0% chert; poor to fair porosity and permeability; no oil indicators. Sand (7850' to 7890) = very light gray; clast size ranges from medium lower to very fine upper; sub round; moderate to well developed sphericity; moderate sorting; polish to chip to impacted texture; sub mature; non to weak silicate cement; slight to moderate clay matrix; dominant grain support with secondary matrix support: loosely attached; composed of 90% quartz; fair to good porosity and permeability; fair1y clean sand; no oil indicators. Tuffaceous siltstone (7900' to 7950') = pale yellowish brown; very poor to poor induration; brittle; mushy; earthy fracture; sub nodular to sub platy habit; earthy luster; silty to ashy texture; massive gradational beds of silt; composed of 80% silt, 20% clay; scattered carbonaceous shale and coal thin beds. · Sand (7955' to 7970') = very light gray; clast size ranges from medium lower to silt; sub round to rounded; moderate to well developed sphericity; poor sorting; polished to pitted texture; sub mature; non to very slight silicate cement; dominant clay/silt structured matrix; dominant matrix support; composed of >90% quartz; poor porosity and permeability; no oil indicators. Tuffaceous siltstone (7980' to 8040') = light brownish gray; poor induration; brittle; mushy; earthy fracture; sub platy to sub tabular habit; earthy luster; silty/ashy texture; massive beds of gradational silts, carbon shale and clay; minor coal beds. Tuffaceous siltstone (8040' - 8100) = medium light gray to brownish gray; poor to moderate induration; brittle; mushy to pasty when rehydrated; often coarse silt to very fine sand; moderate earthy luster; often slightly organic; grading to variably organic tuffaceous claystone with interbedded coal. Sandstone/sand (8080' - 8150) = clast size ranges from medium lower to silt; sub round to rounded; moderate to well developed sphericity; poor sorting; polished to pitted texture; sub mature; non to very slight silicate cement; dominant clay/silt structured matrix; dominant matrix support; composed of 90% quartz, 10% dark various lithic fragments; poor visible porosity; poor permeability. Coal/carbonaceous shale (8150'-8180) = black. to grayish black to brownish black on carbonaceous shale contacts; firm; resinous luster in coal and very earthy luster in carbonaceous shale; matte to smooth texture on contacts; hackly coal fracture; mostly composed of bituminous coal; moderate gas bleeding from cutting. Sandstone / sand (8200' - 8250) = very light gray to light gray; grain size ranges from very fine lower to medium lower; subrounded to angular; moderate to high sphericity; poor1y sorted in silty/occasionally ashy matrix; mostly matrix supported with moderate to slight grain contact; polish texture; composed of 80-90% quartz and 10-20% carbonaceous lithics and silicates; poor to fair visible porosity; fair1y clean sand. · Tuffaceous siltstone / tuffaceous claystone (8270' - 8330') = very pale yellowish brown to light brownish gray; poor to moderate induration; brittle; mushy to pasty when rehydrated; bit grooved fracture and habit; ~ El)()C·H 16 · · · UNOCALe Happy Valley #9 dull earthy luster; clayey to silty to ashy texture; grading to very carbonaceous clay in parts; composed of 70-% silt, 20% clay, 10% carbonaceous and detrital material; locally grading to very fine sand; grading to variably organic tuffaceous claystone. Tuffaceous claystone I tuffaceous siltstone (8330' - 8380') = very light gray to light brownish gray to very pale yellowish brown; slightly to moderately finn; very soluble; moderately silty to very fine sandy (quartz); very slight disseminated carbonaceous silts and fines throughout; moderately earthy luster; clayey to silty to ashy texture; composed of 50% clay, 40% silt, 10% various carbonaceous and detrital material. Sandstone I sand (8390' - 84301 = very light gray to light gray; very fine upper to coarse lower; occasionally scattered very coarse grains of light brown to pale yellowish orange quartz; subrounded to angular; moderate to high sphericity; overall matrix supported with slight to moderate grain contact; grading ash, siltstone and sometimes claystone; 75% quartz, 25% gray to brown to minor pink and tan including silicate grains; occasionally some minor calcite clasts; poor to fair porosity. [~ El)()CH 17 . . UNOCALe RED #2 . SURVEYS True Survey Inclina- Azimuth Course Vertical Vertical Coordinates Closure Dogleg Build Walk Depth tion Length Depth Section N/S EIW Distance Angle Severity Rate Rate (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) (d/100') (d/1 00') (d/100') 0 0.00 0.00 0 0 0.00 0.00 S 0.00 W 0.00 180.00 178 0.39 97.76 178 178.00 -0.59 0.08 S 0.60 E 0.61 97.77 0.22 0.22 54.92 206 0.28 40.18 28 206.00 -0.73 0.04 S 0.74 E 0.74 93.29 1.20 -0.39 -205.64 298 5.76 275.96 92 297.85 3.64 0.61 N 3.71 W 3.76 279.32 6.44 5.96 256.28 391 7.31 275.11 93 390.24 14.05 1.62 N 14.25 W 14.34 276.49 1.67 1.67 -0.91 483 9.52 274.13 92 481.24 27.33 2.69 N 27.67 W 27.80 275.55 2.41 2.40 -1.07 575 11.90 270.93 92 571.64 44.28 3.39 N 44.74 W 44.87 274.34 2.67 2.59 -3.48 668 14.59 268.71 93 662.15 65.51 3.28 N 66.04 W 66.12 272.85 2.94 2.89 -2.39 731 16.18 266.28 63 722.90 82.20 2.54 N 82.74 W 82.78 271.76 2.72 2.52 -3.86 800 18.85 266.20 69 788.69 102.96 1.17 N 103.46 W 103.46 270.65 3.87 3.87 -0.12 850 20.46 266.62 50 835.78 119.77 0.12 N 120.24 W 120.24 270.06 3.23 3.22 0.84 900 22.03 266.97 50 882.38 137.88 0.89 S 138.33 W 138.33 269.63 3.15 3.14 0.70 950 22.91 267.05 50 928.58 156.98 1.88 S 157.41 W 157.42 269.31 1.76 1.76 0.16 1000 23.82 267.09 50 974.48 176.79 2.90 S 177.22 W 177.24 269.06 1.82 1.82 0.08 1050 26.02 266.12 50 1019.82 197.85 4.15 S 198.24 W 198.29 268.80 4.48 4.40 -1.94 1100 27.55 265.75 50 1 064.46 220.38 5.75 S 220.72 W 220.79 268.51 3.08 3.06 -0.74 1150 28.92 265.52 50 1108.50 244.03 7.55 S 244.30 W 244.42 268.23 2.75 2.74 -0.46 1200 30.26 265.30 50 1151.98 268.72 9.53 S 268.91 W 269.08 267.97 2.69 2.68 -0.44 1250 30.84 265.16 50 1195.04 294.14 11.64 S 294.24 W 294.47 267.73 1.17 1.16 -0.28 1300 31.43 265.02 50 1237.84 319.99 13.86 S 320.00 W 320.30 267.52 1.19 1.18 -0.28 1350 35.44 264.65 50 1279.56 347.53 16.34 S 347.43 W 347.81 267.31 8.03 8.02 -0.74 1400 36.36 264.65 50 1320.06 376.85 19.08 S 376.62 W 377.10 267.10 1.84 1.84 0.00 1450 36.47 264.71 50 1360.30 406.53 21.83 S 406.17 W 406.76 266.92 0.23 0.22 0.12 1500 39.80 264.18 50 1399.62 437.40 24.82 S 436.90 W 437.60 266.75 6.69 6.66 -1.06 1550 44.53 263.51 50 1436.67 470.95 28.43 S 470.26 W 471.12 266.54 9.50 9.46 -1.34 1600 45.84 263.36 50 1471.91 506.40 32.48 S 505.49 W 506.54 266.32 2.63 2.62 -0.30 ~ El~C)(~H . . UNOCALe Happy Valley #9 . 1650 46.50 263.35 50 1506.53 542.46 36.66 S 541.32 W 542.56 266.13 1.32 1.32 -0.02 1700 46.84 . 263.40 50 1540.84 578.81 40.85 S 577.45 W 578.89 265.95 0.68 0.68 0.10 1750 47.18 263.45 50 1574.94 615.37 45.04 S 613.78 W 615.43 265.80 0.68 0.68 0.10 1800 49.78 263.74 50 1608.08 652.79 49.21 S 650.98 W 652.84 265.68 5.22 5.20 0.58 1850 49.77 263.74 50 1640.37 690.96 53.38 S 688.93 W 690.99 265.57 0.02 -0.02 0.00 1900 49.70 263.68 50 1672.68 729.10 57.56 S 726.85 W 729.13 265.47 0.17 -0.14 -0.12 1950 49.38 263.39 50 1705.13 767.13 61.84 S 764.65 W 767.15 265.38 0.78 -0.64 -0.58 2000 49.57 263.34 50 1737.62 805.13 66.23 S 802.41 W 805.13 265.28 0.39 0.38 -0.10 2050 49.64 263.13 50 1770.02 843.19 70.72 S 840.22 W 843.19 265.19 0.35 0.14 -0.42 2100 49.53 262.98 50 1802.44 881.23 75.32 S 878.01 W 881.23 265.10 0.32 -0.22 -0.30 2150 49.48 262.93 50 1834.91 919.23 79.98 S 915.75 W 919.23 265.01 0.13 -0.10 -0.10 2200 49.46 262.75 50 1867.40 957.21 84.72 S 953.45 W 957.21 264.92 0.28 -0.04 -0.36 2250 49.37 263.50 50 1899.93 995.16 89.27 S 991.15 W 995.16 264.85 1.15 -0.18 1.50 2300 49.28 264.06 50 1932.52 1033.07 93.38 S 1028.85 W 1033.08 264.81 0.87 -0.18 1.12 2350 49.20 264.44 50 1965.16 1070.94 97.17 S 1066.53 W 1070.95 264.79 0.60 -0.16 0.76 2400 49.14 264.82 50 1997.85 1108.77 100.71 S 1104.20 W 1108.78 264.79 0.59 -0.12 0.76 2450 49.07 265.21 50 2030.59 1146.57 103.99 S 1141.85 W 1146.58 264.80 0.61 -0.14 0.78 2500 49.07 266.07 50 2063.34 1184.34 106.87 S 1179.51 W 1184.35 264.82 1.30 0.00 1.72 2550 49.22 267.80 50 2096.05 1222.13 108.89 S 1217.28 W 1222.14 264.89 2.63 0.30 3.46 2600 49.39 267.87 50 2128.65 1260.00 110.32 S 1255.16 W 1260.00 264.98 0.36 0.34 0.14 2650 49.35 267.72 50 2161.21 1297.90 111 .78 S 1293.08 W 1297.90 265.06 0.24 -0.08 -0.30 2700 49.19 267.49 50 2193.84 1335.75 113.36 S 1330.93 W 1335.75 265.13 0.47 -0.32 -0.46 2750 49.17 267.48 50 2226.52 1373.55 115.02 S 1368.74 W 1373.56 265.20 0.04 -0.04 -0.02 2800 49.22 267.15 50 2259.20 1411.37 116.80 S 1406.54 W 1411.38 265.25 0.51 0.10 -0.66 2850 49.15 266.87 50 2291.88 1449.19 118.77 S 1444.33 W 1449.21 265.30 0.45 -0.14 -0.56 2900 49.09 266.76 50 2324.60 1486.97 120.87 S 1482.08 W 1487.00 265.34 0.21 -0.12 -0.22 2950 49.03 266.64 50 2357.36 1524.72 123.04 S 1519.78 W 1524.76 265.37 0.22 -0.12 -0.24 3000 48.95 266.43 50 2390.17 1562.44 125.32 S 1557.44 W 1562.48 265.40 0.36 -0.16 -0.42 3405 49.44 264.49 405 2654.85 1868.96 149.61 S 1863.01 W 1869.01 265.41 0.38 0.12 -0.48 3500 49.88 263.10 95 2716.35 1941.35 157.44 S 1935.00 W 1941.39 265.35 1.21 0.46 -1.46 3595 50.46 263.87 95 2777.20 2014.28 165.71 S 2007.48 W 2014.31 265.28 0.87 0.61 0.81 [~ EI)()C:H 19 . . UNOCALe Happy Valley #9 . 3689 50.03 262.38 94 2837.31 2086.51 174.36 S 2079.22 W 2086.52 265.21 1.30 -0.46 -1.59 3784 49.08 261.79 95 2898.94 2158.71 184.31 S 2150.83 W 2158.71 265.10 1.11 -1.00 -0.62 3879 46.42 263.72 95 2962.81 2228.96 193.20 S 2220.57 W 2228.96 265.03 3.18 -2.80 2.03 3974 45.83 263.49 95 3028.65 2297.42 200.83 S 2288.63 W 2297.42 264.99 0.65 -0.62 -0.24 4068 44.60 263.64 94 3094.87 2364.12 208.31 S 2354.92 W 2364.12 264.94 1.31 -1.31 0.16 4163 41.92 267.98 95 3164.06 2429.18 213.12 S 2419.81 W 2429.18 264.97 4.21 -2.82 4.57 4258 40.10 267.88 95 3235.75 2491.43 215.37 S 2482.11 W 2491.43 265.04 1.92 -1.92 -0.11 4352 39.22 267.05 94 3308.11 2551.37 218.02 S 2542.04 W 2551.37 265.10 1.09 -0.94 -0.88 4447 38.60 265.22 95 3382.04 2611.02 222.04 S 2601.57 W 2611.02 265.12 1.37 -0.65 -1.93 4542 38.76 264.66 95 3456.20 2670.39 227.28 S 2660.71 W 2670.40 265.12 0.41 0.17 -0.59 4636 38.31 264.66 94 3529.73 2728.95 232.73 S 2719.01 W 2728.96 265.11 0.48 -0.48 0.00 4731 37.29 264.65 95 3604.79 2787.18 238.15 S 2776.99 W 2787.18 265.10 1.07 -1.07 -0.01 4825 34.93 264.80 94 3680.73 2842.57 243.24 S 2832.15 W 2842.57 265.09 2.51 -2.51 0.16 4920 32.51 264.19 95 3759.74 2895.30 248.29 S 2884.64 W 2895.30 265.08 2.57 -2.55 -0.64 5015 29.61 262.91 95 3841.11 2944.29 253.78 S 2933.33 W 2944.29 265.06 3.13 -3.05 -1.35 5110 26.93 263.27 95 3924.77 2989.26 259.20 S 2978.00 W 2989.26 265.03 2.83 -2.82 0.38 5205 25.12 264.16 95 4010.14 3030.92 263.77 S 3019.43 W 3030.92 265.01 1.95 -1.91 0.94 5300 24.91 263.73 95 4096.23 3071.09 268.01 S 3059.37 W 3071.09 264.99 0.29 -0.22 -0.45 5394 24.36 264.87 94 4181.67 3110.27 271.90 S 3098.36 W 3110.27 264.98 0.77 -0.59 1.21 5489 23.75 264.83 95 4268.42 3148.99 275.38 S 3136.93 W 3148.99 264.98 0.64 -0.64 -0.04 5584 23.22 264.71 95 4355.55 3186.85 278.83 S 3174.63 W 3186.85 264.98 0.56 -0.56 -0.13 5679 23.47 266.55 95 4442.77 3224.49 281.69 S 3212.16 W 3224.49 264.99 0.81 0.26 1.94 5773 24.66 266.71 94 4528.60 3262.80 283.94 S 3250.42 W 3262.80 265.01 1.27 1.27 0.17 5868 25.43 266.29 95 4614.67 3303.00 286.40 S 3290.56 W 3303.00 265.03 0.83 0.81 -0.44 5962 26.91 267.31 94 4699.03 3344.44 288.71 S 3331.95 W 3344.44 265.05 1.65 1.57 1.09 6057 27.56 266.91 95 4783.50 3387.88 290.90 S 3375.37 W 3387.89 265.07 0.71 0.68 -0.42 6152 27.06 266.23 95 4867.91 3431 .45 293.51 S 3418.88 W 3431 .46 265.09 0.62 -0.53 -0.72 6247 26.34 266.00 95 4952.78 3474.13 296.40 S 3461.47 W 3474.13 265.11 0.77 -0.76 -0.24 6341 27.25 266.05 94 5036.69 3516.50 299.33 S 3503.74 W 3516.50 265.12 0.97 0.97 0.05 6436 26.76 266.17 95 5121.33 3559.62 302.26 S 3546.78 W 3559.63 265.13 0.52 -0.52 0.13 6531 26.44 266.40 95 5206.27 3602.15 305.02 S 3589.23 W 3602.16 265.14 0.35 -0.34 0.24 ~ El)()(~H 20 . . UNOCALe Happy Valley #9 . 6626 27.14 265.21 95 5291.08 3644.96 308.15 S 3631.93 W 3644.98 265.15 0.93 0.74 -1.25 6720 26.01 264.83 94 5375.14 3687.02 311.80 S 3673.82 W 3687.03 265.15 1.22 -1.20 -0.40 6815 26.72 266.18 95 5460.26 3729.20 315.10 S 3715.88 W 3729.21 265.15 0.98 0.75 1.42 6909 25.57 266.32 94 5544.64 3770.61 317.81 S 3757.21 W 3770.62 265.17 1.23 -1.22 0.15 7004 25.33 265.90 95 5630.42 3811.42 320.58 S 3797.94 W 3811.44 265.18 0.32 -0.25 -0.44 7099 25.24 264.85 95 5716.32 3852.00 323.85 S 3838.38 W 3852.02 265.18 0.48 -0.09 -1.11 7193 24.17 264.59 94 5801.72 3891.28 327.47 S 3877.50 W 3891.30 265.17 1.14 -1.14 -0.28 7288 23.21 265.19 95 5888.71 3929.45 330.87 S 3915.52 W 3929.47 265.17 1.04 -1.01 0.63 7383 22.60 264.87 95 5976.22 3966.43 334.07 S 3952.35 W 3966.44 265.17 0.66 -0.64 -0.34 7478 22.14 264.30 95 6064.07 4002.58 337.48 S 3988.35 W 4002.60 265.16 0.54 -0.48 -0.60 7572 22.22 264.61 94 6151.11 4038.07 340.91 S 4023.67 W 4038.08 265.16 0.15 0.09 0.33 7667 21.96 264.92 95 6239.14 4073.79 344.17 S 4059.24 W 4073.81 265.15 0.30 -0.27 0.33 7762 21.60 265.02 95 6327.36 4109.04 347.26 S 4094.36 W 4109.06 265.15 0.38 -0.38 0.11 7856 21.61 264.80 94 6414.76 4143.65 350.33 S 4128.83 W 4143.67 265.15 0.09 0.01 -0.23 7951 21.28 264.07 95 6503.18 4178.38 353.70 S 4163.40 W 4178.40 265.14 0.45 -0.35 -0.77 8046 20.92 264.02 95 6591.81 4212.58 357.25 S 4197.41 W 4212.59 265.14 0.38 -0.38 -0.05 8140 19.91 263.90 94 6679.90 4245.36 360.70 S 4230.02 W 4245.37 265.13 1.08 -1.07 -0.13 8235 19.04 264.48 95 6769.47 4277.03 363.90 S 4261.53 W 4277.04 265.12 0.94 -0.92 0.61 8330 18.53 264.69 95 6859.41 4307.62 366.79 S 4291.98 W 4307.63 265.12 0.54 -0.54 0.22 8428 18.48 264.87 98 6952.34 4338.72 369.62 S 4322.96 W 4338.73 265.11 0.08 -0.05 0.18 8478 18.48 264.87 50 6999.76 4354.57 371.04 S 4338.74 W 4354.58 265.11 0.00 0.00 0.00 [:I EI)()(~H 21 . . UNOCALe Happy Valley #9 . DAILY MUD PROPERTIES Date I FI Depth Den FV PV YP Gels API Cake Solids NAPlWate Sand PH CI Ca I Temp FiI r 9/12/04 - 0 9.3 67 30 25 6/9111 3.8 1/0 5.2 3/89.5 0.10 9.8 29000 0 9/13/04 63 284 9.3+ 79 28 33 7/9/11 3.6 1/0 4.6 3/90 0.25 9.6 30000 180 9/14/04 62 1"nn 07. 48 12 16 6/8/9 7.4 1/0 2.3 0.5/96.5 0.25 8.6 7400 120 -.. 9/15/04 76 3300 9.2 62 18 24 10/21/28 6.6 1/0 4.6 0/93.5 0.50 8.6 23000 180 9/16/04 - 3300 9.0 48 8 16 4/5/6 6.4 1/0 1.2 0/96.5 0 9.4 27000 160 9/17/04 - 3300 9.0 49 9 18 5/6/7 6.0 1/0 1.4 0/96 0 9.1 31000 160 9/18/04 69 3575 9.0+ 50 12 17 5/6/7 6.0 1/0 1.7 0/96 .10 9.4 28000 140 9/19/04 - 4733 9.2 64 17 22 4/7/9 4.2 1/0 3.0 3/91.5 .10 8.6 31000 200 9/20/04 86 5822 9.2+ 58 17 16 4/7/9 4.0 1/0 3.6 3/91 .10 9.4 30000 160 9/21/04 92 7242 9.4 59 17 13 3/6/8 3.8 1/0 5.6 3/89 .10 8.9 31000 220 9/22/03 101 8478 9.5 59 20 14 4/8112 4.0 1/0 8.6 3/88 .10 8.5 32000 200 9/23/04 88 8478 9.4 57 19 13 4/8/12 4.0 1/0 5.6 3/89 .10 8.5 31500 200 [:I El)O(~H 22 . . UNOCALe Happy Valley #9 . BIT RECORD BIT RECORD Red Pad #2 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 Drilled Hours Ave Ave Ave Ave No. In Out FtlHr WOB RPM PSI 1 8.5 SEC FS2653 1041470 3X16 57' 3300' 3242' 16.5 267 3.2 54 1500 0 5 C S I TD 1 1X12 T - - 2 6.125 HC HCM 406 7102577 3X16 3300' 8478' 5178' 51.4 126 4.3 63 2055 3 2 E A X I TD R - [~ El)OC=H 23 . . . UNOCAL DAIL Y WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sep 13, 2004 DEPTH 789.00 PRESENT OPERATION DRILLING TIME 11 :59 pm YESTERDAY 57.00 24 HOUR FOOTAGE 732 CASING INFORMATION 133/8" @ 57' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1R1 8.5 FS2653 10414701 3X16,1X12 57' 2.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1517.9 @ 169.00 5.8 @ 626.00 454.2 280.23587 FT/HR SURFACE TORQUE 4552 @ 170.00 103 @ 789.00 1336.5 103.48351 AMPS WEIGHT ON BIT 5 @ 737.00 0 @ 257.00 0.9 0.00000 KLBS ROTARY RPM 80 @ 577.00 0 @ 452.00 38.7 -0.42565 RPM PUMP PRESSURE 1858 @ 718.00 52 @ 788.00 944.2 52.51030 PSI DRILLING MUD REPORT DEPTH 284' MW 9.3+ VIS 79 PV 28 YP 33 FL 3.6 Gels 7/9/11 CL- 30000 FC 1/0 SOL 4.6 SD 0.25 OIL 3 MBL pH 9.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 722.00 0 @ 221.00 1.6 TRIP GAS 0 CUTTING GAS 0 @ 789.00 0 @ 789.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 988 @ 724.00 115 @ 695.00 242.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 789.00 0 @ 789.00 0.0 AVG 0 PROPANE (C-3) 0 @ 789.00 0 @ 789.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 789.00 0 @ 789.00 0.0 CURRENT BACKGROUND/AVG 4 PENTANE (C-5) 0 @ 789.00 0 @ 789.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY UNDER NEXT CASING POINT PRESENT LITHOLOGY DAILY INSTALL MOUSE HOLE, PICK UP BALES AND HANG RIG TONGS, PICK UP TEST JOINT, RIG UP AND TEST ACTIVITY BOPE, FLANGE LEAKED ON HYDRILL - TIGHTEN AND RESET, LAY DOWN EQUIPMENT AND INSTALL WEAR SUMMARY RING, PICK UP 4" HWDP AND STAND BACK, PICK UP BHAAND DRILL TO 227', STAND BACK HWDP, PICK UP MWD AND FLEX COLLARS, DRILL AHEAD EPOCH PERSONNEL ON 2 BOARD REPORT BY LEES F. BROWNE JR. DAILY $1875/TOTAL COST FROM 9/10/04 TO 9/13/04 = COST $7820.20 . . . UNOCAL AFE # 163015 DAILY WELLSITE REPORT ~ EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 15, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO RUN 7" CASING TIME 11:59 pm YESTERDAY 1885.00 24 HOUR FOOTAGE 1415 CASING INFORMATION 13.375"@ 56' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300 2578.6 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIB/C PULLED 1RR1 8.5 SEC FS2653 10414701 3X16,1X12 57 3300 3242 16.5 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 331.2 @ 2300.00 20.0 @ 2943.00 225.0 236.13281 FT/HR SURFACE TORQUE 6072 @ 3240.00 103 @ 2288.00 4203.7 5352.42285 AMPS WEIGHT ON BIT 12 @ 2536.00 0 @ 3014.00 5.0 5.87236 KLBS ROTARY RPM 80 @ 2552.00 0 @ 2257.00 71.3 74.30798 RPM PUMP PRESSURE 1821 @ 3240.00 53 @ 2191.00 285.1 1755.60950 PSI DRILLING MUD REPORT DEPTH 3300' MW 9.2 VIS 62 PV 18 YP 24 FL 6.6 Gels 10/21/28 CL- 23000 FC 1/0 SOL 4.6 SD 0.50 OIL 0 MBL pH 8.6 Ca+ 180 CCI MWD SUMMARY I NT.ERV AL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 301 @ 2769.00 2 @ 2514.00 38.8 TRIP GAS 0 CUTTING GAS 0 @ 3300.00 0 @ 3300.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 57095 @ 2769.00 380 @ 2514.00 7300.8 CONNECTION GAS HIGH 3 ETHANE (C-2) 27 @ 2857.00 0 @ 2936.00 2.1 AVG 0-1 PROPANE (C-3) 9 @ 2769.00 0 @ 2760.00 0.1 CURRENT 0 BUTANE (C-4) 0 @ 3300.00 0 @ 3300.00 0.0 CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 0 @ 3300.00 0 @ 3300.00 0.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2758 TO 2820 C-1 57095, C-2 27 C·3 9 BEFORE 20 MAX 301 GAS MAINTAINED CONTENT WITH GRADUAL PPM AFTER40 BLEEDOFF TO 2820' LITHOLOGY SAMPLES CAUGHT UNDER SURFACE CASING AT 3300' PRESENT LITHOLOGY DAILY DRILL TO TO @ 3300', CIRCULATED THE HOLE CLEAN, PUMPED A CARBIDE AND WALNUT SWEEP WITH ACTIVITY "NO" RETURNS ON BOTH, PUMP OUT TO 2950' = TIGHT, BACK REAM OUT, HOLE IS GIVING BACK MUD ON SUMMARY CONNECTIONS, BACK REAM TO 700' AND MONITOR THE WELL, HOLE GAVE BACK 60 BBLS, CONTINUE TO PULL OUT OF THE HOLE AND PREP TO RUN 7" CASING EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 + $50 SERVICE DELIVERY = $1925 REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163015 DAIL Y WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 16, 2004 DEPTH 3300.00 PRESENT OPERATION TEST BOPE TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3300' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 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 @ @ FTlHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH NA MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 29 @ TG @ TRIP GAS 29 @ 3300' CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUNDIAVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE CATCHERS ON UNDER CASING PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RUN 7" CASING AND CEMENT, TEST BOPE . EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 REPORT BY LEES F. BROWNE JR. . . . UNOCAL AFE # 163015 DAIL Y WELLSITE REPORT n EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sep 17, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO DRILL CEMENT TIME 11:59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300' 2595' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300' 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3300' MW 9.0 VIS 49 PV 9 YP 18 FL 6.0 Gels 5/6/7 CL- 31000 FC 1/0 SOL 1.4 SD 0 OIL 0 MBL pH 9.1 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY STARTS UNDER 3300' (SAMPLE CATCHERS ON LOCATION) PRESENT LITHOLOGY CONTINUE TO TEST BOPE, LAY DOWN TEST JOINT, INSTALL WEAR BUSHING, CEMENT TOP JOB 4-5 BBLS, DAILY RUN IN THE HOLE WI GYRO, PULL OUT OF THE HOLE AND RIG DOWN, RIG UP E-LlNE AND RUN IN THE ACTIVITY HOLE AND PERFORM CEMENT BOND LOG, RIG DOWN E-LlNE AND SERVICE THE DRAW WORKS, PICK UP SUMMARY BHA AND RUN IN THE HOLE WITH HWDP FROM THE DERRICK, TEST MWD AND PICK UP DRILLPIPE AND STAND BACK IN THE DERRICK. . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2919 = $2465 + $454 SC MOB REPORT BY LEES F. BROWNE JR. . . UNOCAL AFE #163015 DAILY WELLSITE REPORT n EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 18, 2004 DEPTH 3972.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 672 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4032 3076' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300 6.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 374.4 @ 3512.00 16.1 @ 3663.00 144.8 126.46833 FT/HR SURFACE TORQUE 5104 @ 3518.00 136 @ 3876.00 3470.8 4207.79639 AMPS WEIGHT ON BIT 16 @ 3318.00 SLIDE @ 3557.00 5.0 6.63138 KLBS ROTARY RPM 80 @ 3748.00 SLIDE @ 3751.00 51.9 79.24857 RPM PUMP PRESSURE 1684 @ 3897.00 28 @ 3559.00 940.7 1509.71265 PSI DRILLING MUD REPORT DEPTH 3575' MW 9.0+ VIS 50 PV 12 YP 17 FL 6.0 Gels 5/6/7 CL- 28000 FC 1/0 SOL 1.7 SD .10 OIL 0 MBL pH 9.4 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 3394.00 2 @ 3372.00 17.9 TRIP GAS 2 @ 3300' CUTTING GAS 0 @ 3972.00 0 @ 3972.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 14165 @ 3395.00 489 @ 3372.00 3638.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 56 @ 3327.00 0 @ 3481.00 3.0 AVG 0 PROPANE (C-3) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENTBACKGROUND~VG14 PENTANE (C-5) 0 @ 3972.00 0 @ 3972.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% TUFFACEOUS CLAY, 10% CARBON SHALE, 10% SAND PRESENT LITHOLOGY 100% CLAY RUN IN THE HOLE TO BOTTOM, REPAIR TOP DRIVE, BREAK CIRCULATION AND TAG CEMENT AT 3240', PRE DAILY JOB SAFETY MEETING, CHOKE DRILL, DRILL OUT CEMENT AND FLOAT EQUIPMENT, DRILL NEW HOLE TO ACTIVITY 3320', RIG UP SCHLUMBERGER TO PERFORM FIT, WON'T PUMP, RIG UP TEST PUMP, PERFORM FIT TO 14.2 SUMMARY PPG, DRILL AHEAD TO 3371', MWD FAILURE, CIRCULATE BOTTOMS UP, PUMP DRY JOB AND PULL OUT OF THE HOLE, CHANGE OUT MWD AND ORIENTATE, RUN IN THE HOLE AND DRILL AHEAD. . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. . . . UNOCAL AFE #163015 DAILY WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 20, 2004 DEPTH 6001.00 PRESENT OPERATION DRILLING TIME 11:59 PM YESTERDAY 4732.00 24 HOUR FOOTAGE 1269 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5868 25.43 266.29 4614.67 SURVEY DATA 5773 24.66 266.71 4528.60 5679 23.47 266.55 4442.77 5584 23.22 264.71 4355.55 5489 23.75 264.83 4268.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PULLED 2 6.125" HC HCM406 7102577 3X16 3300 26.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 295.2 @ 5724.00 12.9 @ 5807.00 120.3 95.72952 FT/HR SURFACE TORQUE 7703 @ 5854.00 117 @ 4732.00 4388.9 6527.58594 AMPS WEIGHT ON BIT 20 @ 4732.00 SLIDE @ 5936.00 3.9 1.52489 KLBS ROTARY RPM 81 @ 5477.00 SLIDE @ 4732.00 59.1 75.40835 RPM PUMP PRESSURE 2469 @ 5622.00 1325 @ 5728.00 2060.9 2295.63257 PSI DRILLING MUD REPORT DEPTH 5822' MW 9.2+ VIS 58 PV 17 YP 16 FL 4.0 Gels 4/7/9 CL- 30000 FC 1/0 SOL 3.6 SO 0.10 OIL 3 MBL pH 9.4 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 217 @ 5880.00 3 @ 4734.00 50.1 TRIP GAS 58@4733' CUTTING GAS 0 @ 6001.00 0 @ 6001.00 0.0 WIPER GAS 24 @ 5697' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 45813 @ 5880.00 656 @ 4734.00 9891.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 30 @ 5290.00 0 @ 5461.00 2.7 AVG 0 PROPANE (C-3) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT BACKGROUNDIAVG 25 PENTANE (C-5) 0 @ 6001.00 0 @ 6001.00 0.0 HYDROCARBON 5275' TO 5295' GAS KICK IN SAND SHOWS INTERVAL LlTHOLOGYIREMARKS GAS DESCRIPTION 5275 TO 5295' 70% SAND 30% CLAY BEFORE 40 DURING 137 ABUNDANT CLAY MATRIX WITH FINE TO AFTER 70 MEDIUM GRAIN SANDS LITHOLOGY CLAY, SILT, SAND CARBON SHALE PRESENT LITHOLOGY 6000' = 80% CLAY, 20% SILT DAIL Y ACTIVITY DRILL FORMATION TO 5697', CIRCULATE BOTTOMS UP AND PULL A WIPER TRIP TO THE DEEPEST SUMMARY GHOST REAMER DEPTH, RUN IN THE HOLE AND DRILL AHEAD, WIPER GAS = 24 UNITS OVER BACK GROUND GAS. . . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. . . . UNOCAL AFE # 163015 DAILY WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE 9/23/04 DEPTH 8478.00000 PRESENT OPERATION RUN 3.5" CASING TIME 11:59 PM YESTERDAY 8478.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8478' 18.48 264.87 6999.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM406 7102577 3X16 3300 8478 5178 51.4 3/2-1 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTlHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8478' MW 9.4 VIS 57 PV 19 YP 13 FL 4.0 Gels 4/8/12 CL- 31500 FC 1/0 SOL 5.6 SO 0.10 OIL 3 MBL pH 8.5 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 506 WG @ 8478 9 @ POOH 20 CIRC TRIP GAS CUTTING GAS @ @ WIPER GAS 506 @ TO CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENTBACKGROUND~VG16 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY FINISHED TRIPPING BACK TO BOTTOM WITH NO PROBLEMS, CIRCULATE OUT 506 UNITS OF WIPER GAS ACTIVITY AT TO, CIRCULATE CARBIDE LAG = 25 BBLS WASHOUT OR 11.7%, PULL OUT OF THE HOLE WITH NO SUMMARY PROBLEMS, RIG UP SCHLUMBERGER AND RAN WIRELlNE LOGS, RIG DOWN SCHLUMBEGER AND RIG UP TO RUN 3.5" TUBING, START TO RUN TUBING. EPOCH PERSONNEL ON 3 BOARD REPORT BY LEES F. BROWNE JR. DAILY $2919 (include logger mobilization) TOTAL COST AS OF 9/23/04 COST = $30302.75 . . . UNOCAL DAILY WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sap 13, 2004 DEPTH 789.00 PRESENT OPERATION DRILLING TIME 11 :59 pm YESTERDAY 57.00 24 HOUR FOOTAGE 732 CASING INFORMATION 133/8" @ 57' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1R1 8.5 FS2653 10414701 3X16, 1X12 57' 2.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1517.9 @ 169.00 5.8 @ 626.00 454.2 280.23587 FT/HR SURFACE TORQUE 4552 @ 170.00 103 @ 789.00 1336.5 103.48351 AMPS WEIGHT ON BIT 5 @ 737.00 0 @ 257.00 0.9 0.00000 KLBS ROTARY RPM 80 @ 577.00 0 @ 452.00 38.7 -0.42565 RPM PUMP PRESSURE 1858 @ 718.00 52 @ 788.00 944.2 52.51030 PSI DRILLING MUD REPORT DEPTH 284' MW 9.3+ VIS 79 PV 28 YP 33 FL 3.6 Gels 7/9/11 CL- 30000 FC 1/0 SOL 4.6 SO 0.25 OIL 3 MBL pH 9.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 722.00 0 @ 221.00 1.6 TRIP GAS 0 CUTTING GAS 0 @ 789.00 0 @ 789.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 988 @ 724.00 115 @ 695.00 242.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 789.00 0 @ 789.00 0.0 AVG 0 PROPANE (C-3) 0 @ 789.00 0 @ 789.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 789.00 0 @ 789.00 0.0 CURRENT BACKGROUND/AVG 4 PENTANE (C-5) 0 @ 789.00 0 @ 789.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY UNDER NEXT CASING POINT PRESENT LITHOLOGY DAILY INSTALL MOUSE HOLE, PICK UP BALES AND HANG RIG TONGS, PICK UP TEST JOINT, RIG UP AND TEST ACTIVITY BOPE, FLANGE LEAKED ON HYDRILL - TIGHTEN AND RESET, LAY DOWN EQUIPMENT AND INSTALL WEAR SUMMARY RING, PICK UP 4" HWDP AND STAND BACK, PICK UP BHA AND DRILL TO 227', STAND BACK HWDP, PICK UP MWD AND FLEX COLLARS, DRILL AHEAD EPOCH PERSONNEL ON 2 BOARD REPORT BY LEES F. BROWNE JR. DAILY $1875/ TOTAL COST FROM 9/10104 TO 9/13/04 = COST $7820.20 . UNOCAL AFE # 163015 DAIL Y WELLSITE REPORT U EPOCH HAPPY VALLEY #9 . REPORT FOR DON FOWLER DATE Sep 15, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO RUN 7" CASING TIME 11 :59 pm YESTERDAY 1885.00 24 HOUR FOOTAGE 1415 CASING INFORMATION 13.375" @ 56' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300 2578.6 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR1 8.5 SEC FS2653 10414701 3X16,1X12 57 3300 3242 16.5 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 331.2 @ 2300.00 20.0 @ 2943.00 225.0 236.13281 FTIHR SURFACE TORQUE 6072 @ 3240.00 103 @ 2288.00 4203.7 5352.42285 AMPS WEIGHT ON BIT 12 @ 2536.00 0 @ 3014.00 5.0 5.87236 KLBS ROTARY RPM 80 @ 2552.00 0 @ 2257.00 71.3 74.30798 RPM PUMP PRESSURE 1821 @ 3240.00 53 @ 2191.00 285.1 1755.60950 PSI DRILLING MUD REPORT DEPTH 3300' MW 9.2 VIS 62 PV 18 YP 24 FL 6.6 Gels 10/21/28 CL- 23000 FC 1/0 SOL 4.6 SD 0.50 OIL 0 MBL pH 8.6 Ca+ 180 CCI MWD SUMMARY I NT.ERV AL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 301 @ 2769.00 2 @ 2514.00 38.8 TRIP GAS 0 CUTTING GAS 0 @ 3300.00 0 @ 3300.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 57095 @ 2769.00 380 @ 2514.00 7300.8 CONNECTION GAS HIGH 3 ETHANE (C-2) 27 @ 2857.00 0 @ 2936.00 2.1 AVG 0-1 PROPANE (C-3) 9 @ 2769.00 0 @ 2760.00 0.1 CURRENT 0 BUTANE (C-4) 0 @ 3300.00 0 @ 3300.00 0.0 CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 0 @ 3300.00 0 @ 3300.00 0.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2758 TO 2820 C-1 57095, C-2 27 C-3 9 BEFORE 20 MAX 301 GAS MAINTAINED CONTENT WITH GRADUAL PPM AFTER40 BLEEDOFF TO 2820' LITHOLOGY SAMPLES CAUGHT UNDER SURFACE CASING AT 3300' PRESENT LITHOLOGY DAILY DRILL TO TD @ 3300', CIRCULATED THE HOLE CLEAN, PUMPED A CARBIDE AND WALNUT SWEEP WITH ACTIVITY "NO" RETURNS ON BOTH, PUMP OUT TO 2950' = TIGHT, BACK REAM OUT, HOLE IS GIVING BACK MUD ON SUMMARY CONNECTIONS, BACK REAM TO 700' AND MONITOR THE WELL, HOLE GAVE BACK 60 BBLS, CONTINUE TO PULL OUT OF THE HOLE AND PREP TO RUN 7" CASING . . EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 + $50 SERVICE DELIVERY = $1925 REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163015 DAILY WELLSITE REPORT ~ EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 16, 2004 DEPTH 3300.00 PRESENT OPERATION TEST BOPE TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3300' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIB/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH NA MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 29 @ TG @ TRIP GAS 29 @ 3300' CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY SAMPLE CATCHERS ON UNDER CASING PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RUN 7" CASING AND CEMENT, TEST BOPE . EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 REPORT BY LEES F. BROWNE JR. . . UNOCAL AFE # 163015 DAILY WELLSITE REPORT n EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sap 17, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO DRILL CEMENT TIME 11:59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300' 2595' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300' 0 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 3300' MW 9.0 VIS 49 PV 9 YP 18 FL 6.0 Gels 5/6/7 CL- 31000 FC 1/0 SOL 1.4 SD 0 OIL 0 MBL pH 9.1 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (pprn) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUNDIAVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY STARTS UNDER 3300' (SAMPLE CATCHERS ON LOCATION) PRESENT LITHOLOGY CONTINUE TO TEST BOPE, LAY DOWN TEST JOINT, INSTALL WEAR BUSHING, CEMENT TOP JOB 4-5 BBLS, DAILY RUN IN THE HOLE W/ GYRO, PULL OUT OF THE HOLE AND RIG DOWN, RIG UP E-LlNE AND RUN IN THE ACTIVITY HOLE AND PERFORM CEMENT BOND LOG, RIG DOWN E-LlNE AND SERVICE THE DRAW WORKS, PICK UP SUMMARY BHA AND RUN IN THE HOLE WITH HWDP FROM THE DERRICK, TEST MWD AND PICK UP DRILLPIPE AND STAND BACK IN THE DERRICK. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2919 = $2465 + $454 SC MOB REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163015 DAIL Y WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 18, 2004 DEPTH 3972.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 672 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4032 3076' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300 6.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 374.4 @ 3512.00 16.1 @ 3663.00 144.8 126.46833 FTIHR SURFACE TORQUE 5104 @ 3518.00 136 @ 3876.00 3470.8 4207.79639 AMPS WEIGHT ON BIT 16 @ 3318.00 SLIDE @ 3557.00 5.0 6.63138 KLBS ROTARY RPM 80 @ 3748.00 SLIDE @ 3751.00 51.9 79.24857 RPM PUMP PRESSURE 1684 @ 3897.00 28 @ 3559.00 940.7 1509.71265 PSI DRILLING MUD REPORT DEPTH 3575' MW 9.0+ VIS 50 PV 12 YP 17 FL 6.0 Gels 5/6/7 CL- 28000 FC 1/0 SOL 1.7 SD .10 OIL 0 MBL pH 9.4 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 3394.00 2 @ 3372.00 17.9 TRIP GAS 2 @ 3300' CUTTING GAS 0 @ 3972.00 0 @ 3972.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 14165 @ 3395.00 489 @ 3372.00 3638.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 56 @ 3327.00 0 @ 3481.00 3.0 AVG 0 PROPANE (C-3) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENTBACKGROUND~VG14 PENTANE (C-5) 0 @ 3972.00 0 @ 3972.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% TUFFACEOUS CLAY, 10% CARBON SHALE, 10% SAND PRESENT LITHOLOGY 100% CLAY RUN IN THE HOLE TO BOTTOM, REPAIR TOP DRIVE, BREAK CIRCULATION AND TAG CEMENT AT 3240', PRE DAILY JOB SAFETY MEETING, CHOKE DRILL, DRILL OUT CEMENT AND FLOAT EQUIPMENT, DRILL NEW HOLE TO ACTIVITY 3320', RIG UP SCHLUMBERGER TO PERFORM FIT, WON'T PUMP, RIG UP TEST PUMP, PERFORM FIT TO 14.2 SUMMARY PPG, DRILL AHEAD TO 3371', MWD FAILURE, CIRCULATE BOTTOMS UP, PUMP DRY JOB AND PULL OUT OF THE HOLE, CHANGE OUT MWD AND ORIENTATE, RUN IN THE HOLE AND DRILL AHEAD. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. · UNOCAL AFE #163015 DAILY WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sap 20, 2004 DEPTH 6001.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 4732.00 24 HOUR FOOTAGE 1269 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5868 25.43 266.29 4614.67 SURVEY DATA 5773 24.66 266.71 4528.60 5679 23.47 266.55 4442.77 5584 23.22 264.71 4355.55 5489 23.75 264.83 4268.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM406 7102577 3X16 3300 26.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 295.2 @ 5724.00 12.9 @ 5807.00 120.3 95.72952 FTlHR SURFACE TORQUE 7703 @ 5854.00 117 @ 4732.00 4388.9 6527.58594 AMPS WEIGHT ON BIT 20 @ 4732.00 SLIDE @ 5936.00 3.9 1.52489 KLBS ROTARY RPM 81 @ 5477.00 SLIDE @ 4732.00 59.1 75.40835 RPM PUMP PRESSURE 2469 @ 5622.00 1325 @ 5728.00 2060.9 2295.63257 PSI DRILLING MUD REPORT DEPTH 5822' MW 9.2+ VIS 58 PV 17 YP 16 FL 4.0 Gels 4/7/9 CL- 30000 FC 1/0 SOL 3.6 SD 0.10 OIL 3 MBL pH 9.4 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 217 @ 5880.00 3 @ 4734.00 50.1 TRIP GAS 58 @ 4733' CUTTING GAS 0 @ 6001.00 0 @ 6001.00 0.0 WIPER GAS 24 @ 5697' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 45813 @ 5880.00 656 @ 4734.00 9891.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 30 @ 5290.00 0 @ 5461.00 2.7 AVG 0 PROPANE (C-3) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT BACKGROUND/AVG 25 PENTANE (C-5) 0 @ 6001.00 0 @ 6001.00 0.0 HYDROCARBON 5275' TO 5295' GAS KICK IN SAND SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5275 TO 5295' 70% SAND 30% CLAY BEFORE 40 DURING 137 ABUNDANT CLAY MATRIX WITH FINE TO AFTER 70 MEDIUM GRAIN SANDS LITHOLOGY CLAY, SILT, SAND CARBON SHALE PRESENT LITHOLOGY 6000' = 80% CLAY, 20% SILT DAILY ACTIVITY DRILL FORMATION TO 5697', CIRCULATE BOTTOMS UP AND PULL A WIPER TRIP TO THE DEEPEST SUMMARY GHOST REAMER DEPTH, RUN IN THE HOLE AND DRILL AHEAD, WIPER GAS = 24 UNITS OVER BACK GROUND GAS. · · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. . . . · · · UNOCAL AFE # 163015 DAILY WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE 9/23/04 DEPTH 8478.00000 PRESENT OPERATION RUN 3.5" CASING TIME 11 :59 PM YESTERDAY 8478.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7"@ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8478' 18.48 264.87 6999.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIB/C PULLED 2 6.125" HC HCM406 7102577 3X16 3300 8478 5178 51.4 3/2-1 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8478' MW 9.4 VIS 57 PV 19 YP 13 FL 4.0 Gels 4/8/12 CL- 31500 FC 1/0 SOL 5.6 SD 0.10 OIL 3 MBL pH 8.5 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 506 WG @ 8478 9 @ POOH 20 CIRC TRIP GAS CUTTING GAS @ @ WIPER GAS 506 @ TD CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENTBACKGROUND~VG16 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY FINISHED TRIPPING BACK TO BOTTOM WITH NO PROBLEMS, CIRCULATE OUT 506 UNITS OF WIPER GAS ACTIVITY AT TD, CIRCULATE CARBIDE LAG = 25 BBLS WASHOUT OR 11.7%, PULL OUT OF THE HOLE WITH NO SUMMARY PROBLEMS, RIG UP SCHLUMBERGER AND RAN WIRELlNE LOGS, RIG DOWN SCHLUMBEGER AND RIG UP TO RUN 3.5" TUBING, START TO RUN TUBING. EPOCH PERSONNEL ON 3 BOARD REPORT BY LEES F. BROWNE JR. DAILY $2919 (include logger mobilization) TOTAL COST AS OF 9/23/04 COST = $30302.75 . . . UNOCAL DAILY WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sep 13, 2004 DEPTH 789.00 PRESENT OPERATION DRILLING TIME 11 :59 pm YESTERDAY 57.00 24 HOUR FOOTAGE 732 CASING INFORMATION 133/8" @ 57' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1R1 8.5 FS2653 10414701 3X16, 1X12 57' 2.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1517.9 @ 169.00 5.8 @ 626.00 454.2 280.23587 FT/HR SURFACE TORQUE 4552 @ 170.00 103 @ 789.00 1336.5 103.48351 AMPS WEIGHT ON BIT 5 @ 737.00 0 @ 257.00 0.9 0.00000 KLBS ROTARY RPM 80 @ 577.00 0 @ 452.00 38.7 -0.42565 RPM PUMP PRESSURE 1858 @ 718.00 52 @ 788.00 944.2 52.51030 PSI DRILLING MUD REPORT DEPTH 284' MW 9.3+ VIS 79 PV 28 YP 33 FL 3.6 Gels 7/9/11 CL- 30000 FC 1/0 SOL 4.6 SO 0.25 OIL 3 MBL pH 9.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 722.00 0 @ 221.00 1.6 TRIP GAS 0 CUTTING GAS 0 @ 789.00 0 @ 789.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 988 @ 724.00 115 @ 695.00 242.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 789.00 0 @ 789.00 0.0 AVG 0 PROPANE (C-3) 0 @ 789.00 0 @ 789.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 789.00 0 @ 789.00 0.0 CURRENT BACKGROUND/AVG 4 PENTANE (C-5) 0 @ 789.00 0 @ 789.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY UNDER NEXT CASING POINT PRESENT LITHOLOGY DAILY INSTALL MOUSE HOLE, PICK UP BALES AND HANG RIG TONGS, PICK UP TEST JOINT, RIG UP AND TEST ACTIVITY BOPE, FLANGE LEAKED ON HYDRILL - TIGHTEN AND RESET, LAY DOWN EQUIPMENT AND INSTALL WEAR SUMMARY RING, PICK UP 4" HWDP AND STAND BACK, PICK UP BHA AND DRILL TO 227', STAND BACK HWDP, PICK UP MWD AND FLEX COLLARS, DRILL AHEAD EPOCH PERSONNEL ON 2 BOARD REPORT BY LEES F. BROWNE JR. DAILY $1875/ TOTAL COST FROM 9/10/04 TO 9/13104 = COST $7820.20 . . . UNOCAL AFE # 163015 DAIL Y WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 15, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO RUN 7" CASING TIME 11 :59 pm YESTERDAY 1885.00 24 HOUR FOOTAGE 1415 CASING INFORMATION 13.375" @ 56' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300 2578.6 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR1 8.5 SEC FS2653 10414701 3X16,1X12 57 3300 3242 16.5 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 331.2 @ 2300.00 20.0 @ 2943.00 225.0 236.13281 FTlHR SURFACE TORQUE 6072 @ 3240.00 103 @ 2288.00 4203.7 5352.42285 AMPS WEIGHT ON BIT 12 @ 2536.00 0 @ 3014.00 5.0 5.87236 KLBS ROTARY RPM 80 @ 2552.00 0 @ 2257.00 71.3 74.30798 RPM PUMP PRESSURE 1821 @ 3240.00 53 @ 2191.00 285.1 1755.60950 PSI DRILLING MUD REPORT DEPTH 3300' MW 9.2 VIS 62 PV 18 YP 24 FL 6.6 Gels 10/21/28 CL- 23000 FC 1/0 SOL 4.6 SD 0.50 OIL 0 MBL pH 8.6 Ca+ 180 CCI MWD SUMMARY I NT.ERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 301 @ 2769.00 2 @ 2514.00 38.8 TRIP GAS 0 CUTTING GAS 0 @ 3300.00 0 @ 3300.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 57095 @ 2769.00 380 @ 2514.00 7300.8 CONNECTION GAS HIGH 3 ETHANE (C-2) 27 @ 2857.00 0 @ 2936.00 2.1 AVG 0-1 PROPANE (C-3) 9 @ 2769.00 0 @ 2760.00 0.1 CURRENT 0 BUTANE (C-4) 0 @ 3300.00 0 @ 3300.00 0.0 CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 0 @ 3300.00 0 @ 3300.00 0.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2758 TO 2820 C-1 57095, C-2 27 C-3 9 BEFORE 20 MAX 301 GAS MAINTAINED CONTENT WITH GRADUAL PPM AFTER40 BLEEDOFF TO 2820' LITHOLOGY SAMPLES CAUGHT UNDER SURFACE CASING AT 3300' PRESENT LITHOLOGY DAILY DRILL TO TO @ 3300', CIRCULATED THE HOLE CLEAN, PUMPED A CARBIDE AND WALNUT SWEEP WITH ACTIVITY "NO" RETURNS ON BOTH, PUMP OUT TO 2950' = TIGHT, BACK REAM OUT, HOLE IS GIVING BACK MUD ON SUMMARY CONNECTIONS, BACK REAM TO 700' AND MONITOR THE WELL, HOLE GAVE BACK 60 BBLS, CONTINUE TO PULL OUT OF THE HOLE AND PREP TO RUN 7" CASING EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 + $50 SERVICE DELIVERY = $1925 REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163015 DAILY WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 16, 2004 DEPTH 3300.00 PRESENT OPERATION TEST BOPE TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3300' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 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 @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH NA MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 29 @ TG @ TRIP GAS 29 @ 3300' CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE CATCHERS ON UNDER CASING PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RUN 7" CASING AND CEMENT, TEST BOPE . EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 REPORT BY LEES F. BROWNE JR. . . . . UNOCAL AFE # 163015 DAIL Y WELLSITE REPORT o EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sep 17, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO DRILL CEMENT TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300' 2595' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300' 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTlHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3300' MW 9.0 VIS 49 PV 9 YP 18 FL 6.0 Gels 5/6/7 CL- 31000 FC 1/0 SOL 1.4 SD 0 OIL 0 MBL pH 9.1 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY STARTS UNDER 3300' (SAMPLE CATCHERS ON LOCATION) PRESENT LITHOLOGY CONTINUE TO TEST BOPE, LAY DOWN TEST JOINT, INSTALL WEAR BUSHING, CEMENT TOP JOB 4-5 BBLS, DAILY RUN IN THE HOLE W/ GYRO, PULL OUT OF THE HOLE AND RIG DOWN, RIG UP E-LlNE AND RUN IN THE ACTIVITY HOLE AND PERFORM CEMENT BOND LOG, RIG DOWN E-LlNE AND SERVICE THE DRAW WORKS, PICK UP SUMMARY BHA AND RUN IN THE HOLE WITH HWDP FROM THE DERRICK, TEST MWD AND PICK UP DRILLPIPE AND STAND BACK IN THE DERRICK. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2919 = $2465 + $454 SC MOB REPORT BY LEES F. BROWNE JR. · · · UNOCAL AFE #163015 DAIL Y WELLSITE REPORT [;I EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 18, 2004 DEPTH 3972.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 672 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4032 3076' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIB/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300 6.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 374.4 @ 3512.00 16.1 @ 3663.00 144.8 126.46833 FT/HR SURFACE TORQUE 5104 @ 3518.00 136 @ 3876.00 3470.8 4207.79639 AMPS WEIGHT ON BIT 16 @ 3318.00 SLIDE @ 3557.00 5.0 6.63138 KLBS ROTARY RPM 80 @ 3748.00 SLIDE @ 3751.00 51.9 79.24857 RPM PUMP PRESSURE 1684 @ 3897.00 28 @ 3559.00 940.7 1509.71265 PSI DRILLING MUD REPORT DEPTH 3575' MW 9.0+ VIS 50 PV 12 YP 17 FL 6.0 Gels 5/6/7 CL- 28000 FC 1/0 SOL 1.7 SO .10 OIL 0 MBL pH 9.4 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 3394.00 2 @ 3372.00 17.9 TRIP GAS 2 @ 3300' CUTTING GAS 0 @ 3972.00 0 @ 3972.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 14165 @ 3395.00 489 @ 3372.00 3638.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 56 @ 3327.00 0 @ 3481.00 3.0 AVG 0 PROPANE (C-3) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENTBACKGROUND/AVG14 PENTANE (C-5) 0 @ 3972.00 0 @ 3972.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 80% TUFFACEOUS CLAY, 10% CARBON SHALE, 10% SAND PRESENT LITHOLOGY 100% CLAY RUN IN THE HOLE TO BOTTOM, REPAIR TOP DRIVE, BREAK CIRCULATION AND TAG CEMENT AT 3240', PRE DAILY JOB SAFETY MEETING, CHOKE DRILL, DRILL OUT CEMENT AND FLOAT EQUIPMENT, DRILL NEW HOLE TO ACTIVITY 3320', RIG UP SCHLUMBERGER TO PERFORM FIT, WON'T PUMP, RIG UP TEST PUMP, PERFORM FIT TO 14.2 SUMMARY PPG, DRILL AHEAD TO 3371', MWD FAILURE, CIRCULATE BOTTOMS UP, PUMP DRY JOB AND PULL OUT OF THE HOLE, CHANGE OUT MWD AND ORIENTATE, RUN IN THE HOLE AND DRILL AHEAD. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. . . . UNOCAL AFE #163015 DAILY WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 20, 2004 DEPTH 6001.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 4732.00 24 HOUR FOOTAGE 1269 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5868 25.43 266.29 4614.67 SURVEY DATA 5773 24.66 266.71 4528.60 5679 23.47 266.55 4442.77 5584 23.22 264.71 4355.55 5489 23.75 264.83 4268.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM406 7102577 3X16 3300 26.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 295.2 @ 5724.00 12.9 @ 5807.00 120.3 95.72952 FTlHR SURFACE TORQUE 7703 @ 5854.00 117 @ 4732.00 4388.9 6527.58594 AMPS WEIGHT ON BIT 20 @ 4732.00 SLIDE @ 5936.00 3.9 1.52489 KLBS ROTARY RPM 81 @ 5477.00 SLIDE @ 4732.00 59.1 75.40835 RPM PUMP PRESSURE 2469 @ 5622.00 1325 @ 5728.00 2060.9 2295.63257 PSI DRILLING MUD REPORT DEPTH 5822' MW 9.2+ VIS 58 PV 17 YP 16 FL 4.0 Gels 4/7/9 CL- 30000 FC 1/0 SOL 3.6 SD 0.10 OIL 3 MBL pH 9.4 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 217 @ 5880.00 3 @ 4734.00 50.1 TRIP GAS 58 @ 4733' CUTTING GAS 0 @ 6001.00 0 @ 6001.00 0.0 WIPER GAS 24 @ 5697' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 45813 @ 5880.00 656 @ 4734.00 9891.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 30 @ 5290.00 0 @ 5461.00 2.7 AVG 0 PROPANE (C-3) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT BACKGROUND/AVG 25 PENTANE (C-5) 0 @ 6001.00 0 @ 6001.00 0.0 HYDROCARBON 5275' TO 5295' GAS KICK IN SAND SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5275 TO 5295' 70% SAND 30% CLAY BEFORE 40 DURING 137 ABUNDANT CLAY MATRIX WITH FINE TO AFTER 70 MEDIUM GRAIN SANDS LITHOLOGY CLAY, SILT, SAND CARBON SHALE PRESENT LITHOLOGY 6000' = 80% CLAY, 20% SILT DAILY ACTIVITY DRILL FORMATION TO 5697', CIRCULATE BOTTOMS UP AND PULL A WIPER TRIP TO THE DEEPEST SUMMARY GHOST REAMER DEPTH, RUN IN THE HOLE AND DRILL AHEAD, WIPER GAS = 24 UNITS OVER BACK GROUND GAS. . . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. . . . UNOCAL AFE # 163015 DAIL Y WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE 9/23/04 DEPTH 8478.00000 PRESENT OPERATION RUN 3.5" CASING TIME 11 :59 PM YESTERDAY 8478.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7"@ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8478' 18.48 264.87 6999.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM406 7102577 3X16 3300 8478 5178 51.4 3/2-1 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FTlHR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8478' MW 9.4 VIS 57 PV 19 YP 13 FL 4.0 Gels 4/8/12 CL- 31500 FC 1/0 SOL 5.6 SO 0.10 OIL 3 MBL pH 8.5 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 506 WG @ 8478 9 @ POOH 20 CIRC TRIP GAS CUTTING GAS @ @ WIPER GAS 506 @ TO CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENTBACKGROUND/AVG16 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY FINISHED TRIPPING BACK TO BOTTOM WITH NO PROBLEMS, CIRCULATE OUT 506 UNITS OF WIPER GAS ACTIVITY AT TO, CIRCULATE CARBIDE LAG = 25 BBLS WASHOUT OR 11.7%, PULL OUT OF THE HOLE WITH NO SUMMARY PROBLEMS, RIG UP SCHLUMBERGER AND RAN WIRELlNE LOGS, RIG DOWN SCHLUMBEGER AND RIG UP TO RUN 3.5" TUBING, START TO RUN TUBING. EPOCH PERSONNEL ON 3 BOARD REPORT BY LEES F. BROWNE JR. DAILY $2919 (include logger mobilization) TOTAL COST AS OF 9/23/04 COST = $30302.75 . UNOCAL DAIL Y WELLSITE REPORT EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sep 13, 2004 DEPTH 789.00 PRESENT OPERATION DRILLING TIME 11 :59 pm YESTERDAY 57.00 24 HOUR FOOTAGE 732 CASING INFORMATION 133/8" @ 57' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PU LLED 1R1 8.5 FS2653 10414701 3X16,1X12 57' 2.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1517.9 @ 169.00 5.8 @ 626.00 454.2 280.23587 FT/HR SURFACE TORQUE 4552 @ 170.00 103 @ 789.00 1336.5 103.48351 AMPS WEIGHT ON BIT 5 @ 737.00 0 @ 257.00 0.9 0.00000 KLBS ROTARY RPM 80 @ 577.00 0 @ 452.00 38.7 -0.42565 RPM PUMP PRESSURE 1858 @ 718.00 52 @ 788.00 944.2 52.51030 PSI DRILLING MUD REPORT DEPTH 284' MW 9.3+ VIS 79 PV 28 YP 33 FL 3.6 Gels 7/9/11 CL- 30000 FC 1/0 SOL 4.6 SD 0.25 OIL 3 MBL pH 9.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 5 @ 722.00 0 @ 221.00 1.6 TRIP GAS 0 CUTTING GAS 0 @ 789.00 0 @ 789.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 988 @ 724.00 115 @ 695.00 242.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 789.00 0 @ 789.00 0.0 AVG 0 PROPANE (C-3) 0 @ 789.00 0 @ 789.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 789.00 0 @ 789.00 0.0 CURRENT BACKGROUND/AVG 4 PENTANE (C-5) 0 @ 789.00 0 @ 789.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY UNDER NEXT CASING POINT PRESENT LITHOLOGY DAILY INSTALL MOUSE HOLE, PICK UP BALES AND HANG RIG TONGS, PICK UP TEST JOINT, RIG UP AND TEST ACTIVITY BOPE, FLANGE LEAKED ON HYDRILL - TIGHTEN AND RESET, LAY DOWN EQUIPMENT AND INSTALL WEAR SUMMARY RING, PICK UP 4" HWDP AND STAND BACK, PICK UP BHA AND DRILL TO 227', STAND BACK HWDP, PICK UP MWD AND FLEX COLLARS, DRILL AHEAD . . EPOCH PERSONNEL ON 2 BOARD REPORT BY LEES F. BROWNE JR. DAILY $1875/ TOTAL COST FROM 9/10/04 TO 9/13/04 = COST $7820.20 . UNOCAL AFE # 163015 DAILY WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 15, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO RUN 7" CASING TIME 11 :59 pm YESTERDAY 1885.00 24 HOUR FOOTAGE 1415 CASING INFORMATION 13.375" @ 56' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300 2578.6 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1RR1 8.5 SEC FS2653 10414701 3X16,1X12 57 3300 3242 16.5 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 331.2 @ 2300.00 20.0 @ 2943.00 225.0 236.13281 FT/HR SURFACE TORQUE 6072 @ 3240.00 103 @ 2288.00 4203.7 5352.42285 AMPS WEIGHT ON BIT 12 @ 2536.00 0 @ 3014.00 5.0 5.87236 KLBS ROTARY RPM 80 @ 2552.00 0 @ 2257.00 71.3 74.30798 RPM PUMP PRESSURE 1821 @ 3240.00 53 @ 2191.00 285.1 1755.60950 PSI DRILLING MUD REPORT DEPTH 3300' MW 9.2 VIS 62 PV 18 YP 24 FL 6.6 Gels 10/21/28 CL- 23000 FC 1/0 SOL 4.6 SD 0.50 OIL 0 MBL pH 8.6 Ca+ 180 CCI MWD SUMMARY INT.ERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 301 @ 2769.00 2 @ 2514.00 38.8 TRIP GAS 0 CUTTING GAS 0 @ 3300.00 0 @ 3300.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 57095 @ 2769.00 380 @ 2514.00 7300.8 CONNECTION GAS HIGH 3 ETHANE (C-2) 27 @ 2857.00 0 @ 2936.00 2.1 AVG 0-1 PROPANE (C-3) 9 @ 2769.00 0 @ 2760.00 0.1 CURRENT 0 BUTANE (C-4) 0 @ 3300.00 0 @ 3300.00 0.0 CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 0 @ 3300.00 0 @ 3300.00 0.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2758 TO 2820 C-1 57095, C-2 27 C-3 9 BEFORE 20 MAX 301 GAS MAINTAINED CONTENT WITH GRADUAL PPM AFTER40 BLEEDOFF TO 2820' LITHOLOGY SAMPLES CAUGHT UNDER SURFACE CASING AT 3300' PRESENT LITHOLOGY DAILY DRILL TO TD @ 3300', CIRCULATED THE HOLE CLEAN, PUMPED A CARBIDE AND WALNUT SWEEP WITH ACTIVITY "NO" RETURNS ON BOTH, PUMP OUT TO 2950' = TIGHT, BACK REAM OUT, HOLE IS GIVING BACK MUD ON SUMMARY CONNECTIONS, BACK REAM TO 700' AND MONITOR THE WELL, HOLE GAVE BACK 60 BBLS, CONTINUE TO PULL OUT OF THE HOLE AND PREP TO RUN 7" CASING . . EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 + $50 SERVICE DELIVERY = $1925 REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163015 DAILY WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 16, 2004 DEPTH 3300.00 PRESENT OPERATION TEST BOPE TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3300' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIBIC PU LLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH NA MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 29 @ TG @ TRIP GAS 29 @ 3300' CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY SAMPLE CATCHERS ON UNDER CASING PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RUN 7" CASING AND CEMENT, TEST BOPE . EPOCH PERSONNEL ON BOARD 2 DAILY COST $1875 REPORT BY LEES F. BROWNE JR. . . UNOCAL AFE # 163015 DAIL Y WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR JIM BROWN DATE Sep 17, 2004 DEPTH 3300.00 PRESENT OPERATION PREP TO DRILL CEMENT TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3300' 2595' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300' 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3300' MW 9.0 VIS 49 PV 9 YP 18 FL 6.0 Gels 5/6/7 CL- 31000 FC 1/0 SOL 1.4 SD 0 OIL 0 MBL pH 9.1 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUNDIAVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY IRE MARKS GAS DESCRIPTION LITHOLOGY LITHOLOGY STARTS UNDER 3300' (SAMPLE CATCHERS ON LOCATION) PRESENT LITHOLOGY CONTINUE TO TEST BOPE, LAY DOWN TEST JOINT, INSTALL WEAR BUSHING, CEMENT TOP JOB 4-5 BBLS, DAILY RUN IN THE HOLE W/ GYRO, PULL OUT OF THE HOLE AND RIG DOWN, RIG UP E-LlNE AND RUN IN THE ACTIVITY HOLE AND PERFORM CEMENT BOND LOG, RIG DOWN E-LlNE AND SERVICE THE DRAW WORKS, PICK UP SUMMARY BHA AND RUN IN THE HOLE WITH HWDP FROM THE DERRICK, TEST MWD AND PICK UP DRILLPIPE AND STAND BACK IN THE DERRICK. . . EPOCH PERSONNEL ON BOARD 4 DAILY COST $2919 = $2465 + $454 SC MOB REPORT BY LEES F. BROWNE JR. · UNOCAL AFE #163015 DAILY WELLSITE REPORT EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 18, 2004 DEPTH 3972.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 3300.00 24 HOUR FOOTAGE 672 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4032 3076' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM 406 7102577 3X16 3300 6.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 374.4 @ 3512.00 16.1 @ 3663.00 144.8 126.46833 FT/HR SURFACE TORQUE 5104 @ 3518.00 136 @ 3876.00 3470.8 4207.79639 AMPS WEIGHT ON BIT 16 @ 3318.00 SLIDE @ 3557.00 5.0 6.63138 KLBS ROTARY RPM 80 @ 3748.00 SLIDE @ 3751.00 51.9 79.24857 RPM PUMP PRESSURE 1684 @ 3897.00 28 @ 3559.00 940.7 1509.71265 PSI DRILLING MUD REPORT DEPTH 3575' MW 9.0+ VIS 50 PV 12 YP 17 FL 6.0 Gels 5/6/7 CL- 28000 FC 1/0 SOL 1.7 SD .10 OIL 0 MBL pH 9.4 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 3394.00 2 @ 3372.00 17.9 TRIP GAS 2@3300' CUTTING GAS 0 @ 3972.00 0 @ 3972.00 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 14165 @ 3395.00 489 @ 3372.00 3638.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 56 @ 3327.00 0 @ 3481.00 3.0 AVG 0 PROPANE (C-3) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3972.00 0 @ 3972.00 0.0 CURRENTBACKGROUNDMVG14 PENTANE (C-5) 0 @ 3972.00 0 @ 3972.00 0.0 HYDROCARBON SHOWS NO SHOWS INTERVAL LITHOLOGY IREMARKS GAS DESCRIPTION LITHOLOGY 80% TUFFACEOUS CLAY, 10% CARBON SHALE, 10% SAND PRESENT LITHOLOGY 100% CLAY RUN IN THE HOLE TO BOTTOM, REPAIR TOP DRIVE, BREAK CIRCULATION AND TAG CEMENT AT 3240', PRE DAILY JOB SAFETY MEETING, CHOKE DRILL, DRILL OUT CEMENT AND FLOAT EQUIPMENT, DRILL NEW HOLE TO ACTIVITY 3320', RIG UP SCHLUMBERGER TO PERFORM FIT, WON'T PUMP, RIG UP TEST PUMP, PERFORM FIT TO 14.2 SUMMARY PPG, DRILL AHEAD TO 3371', MWD FAILURE, CIRCULATE BOTTOMS UP, PUMP DRY JOB AND PULL OUT OF THE HOLE, CHANGE OUT MWD AND ORIENTATE, RUN IN THE HOLE AND DRILL AHEAD. · · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. . UNOCAL AFE #163015 DAILY WELLSITE REPORT U EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE Sep 20, 2004 DEPTH 6001.00 PRESENT OPERATION DRILLING TIME 11 :59 PM YESTERDAY 4732.00 24 HOUR FOOTAGE 1269 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5868 25.43 266.29 4614.67 5773 24.66 266.71 4528.60 SURVEY DATA 5679 23.47 266.55 4442.77 5584 23.22 264.71 4355.55 5489 23.75 264.83 4268.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" HC HCM406 7102577 3X16 3300 26.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 295.2 @ 5724.00 12.9 @ 5807.00 120.3 95.72952 FT/HR SURFACE TORQUE 7703 @ 5854.00 117 @ 4732.00 4388.9 6527.58594 AMPS WEIGHT ON BIT 20 @ 4732.00 SLIDE @ 5936.00 3.9 1.52489 KLBS ROTARY RPM 81 @ 5477.00 SLIDE @ 4732.00 59.1 75.40835 RPM PUMP PRESSURE 2469 @ 5622.00 1325 @ 5728.00 2060.9 2295.63257 PSI DRILLING MUD REPORT DEPTH 5822' MW 9.2+ VIS 58 PV 17 YP 16 FL 4.0 Gels 4/7/9 CL- 30000 FC 1/0 SOL 3.6 SD 0.10 OIL 3 MBL pH 9.4 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 217 @ 5880.00 3 @ 4734.00 50.1 TRIP GAS 58 @ 4733' CUTTING GAS 0 @ 6001.00 0 @ 6001.00 0.0 WIPER GAS 24 @ 5697' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 45813 @ 5880.00 656 @ 4734.00 9891.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 30 @ 5290.00 0 @ 5461.00 2.7 AVG 0 PROPANE (C-3) 0 @ 6001.00 0 @ 6001.00 0.0 CU RRENT 0 BUTANE (C-4) 0 @ 6001.00 0 @ 6001.00 0.0 CURRENT BACKGROUNDIAVG 25 PENTANE (C-5) 0 @ 6001 .00 0 @ 6001.00 0.0 HYDROCARBON 5275' TO 5295' GAS KICK IN SAND SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 5275 TO 5295' 70% SAND 30% CLAY BEFORE 40 DURING 137 ABUNDANT CLAY MATRIX WITH FINE TO AFTER 70 MEDIUM GRAIN SANDS LITHOLOGY CLAY, SILT, SAND CARBON SHALE PRESENT LITHOLOGY 6000' = 80% CLAY, 20% SILT DAILY ACTIVITY DRILL FORMATION TO 5697', CIRCULATE BOTTOMS UP AND PULL A WIPER TRIP TO THE DEEPEST SUMMARY GHOST REAMER DEPTH, RUN IN THE HOLE AND DRILL AHEAD, WIPER GAS = 24 UNITS OVER BACK GROUND GAS. . . · EPOCH PERSONNEL ON BOARD 4 DAILY COST $2465 REPORT BY LEES F. BROWNE JR. · · . UNOCAL AFE # 163015 DAILY WELLSITE REPORT g EPOCH HAPPY VALLEY #9 REPORT FOR DON FOWLER DATE 9/23/04 DEPTH 8478.00000 PRESENT OPERATION RUN 3.5" CASING TIME 11 :59 PM YESTERDAY 8478.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3293' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8478' 18.48 264.87 6999.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.125" He HCM406 7102577 3X16 3300 8478 5178 51.4 3/2-1 TO DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8478' MW 9.4 VIS 57 PV 19 YP 13 FL 4.0 Gels 4/8/12 CL- 31500 FC 1/0 SOL 5.6 SD 0.10 OIL 3 MBL pH 8.5 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 506 WG @ 8478 9 @ POOH 20 CIRC TRIP GAS CUTTING GAS @ @ WIPER GAS 506 @ TO CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENTBACKGROUNDAAVG16 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY FINISHED TRIPPING BACK TO BOTTOM WITH NO PROBLEMS, CIRCULATE OUT 506 UNITS OF WIPER GAS ACTIVITY AT TO, CIRCULATE CARBIDE LAG = 25 BBLS WASHOUT OR 11.7%, PULL OUT OF THE HOLE WITH NO SUMMARY PROBLEMS, RIG UP SCHLUMBERGER AND RAN WIRELlNE LOGS, RIG DOWN SCHLUMBEGER AND RIG UP TO RUN 3.5" TUBING, START TO RUN TUBING. . . EPOCH PERSONNEL ON 3 BOARD REPORT BY LEES F. BROWNE JR. DAILY $2919 (include logger mobilization) TOTAL COST AS OF 9/23/04 COST = $30302.75