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210-145
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/14/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240314 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/20/2024 AK E-LINE GPT/PL BCU 13 50133205250000 203138 1/4/2023 AK E-LINE JetCut/CBL BRU 221-35 50283201930000 223077 11/18/2023 AK E-LINE Perf HV B-13 50231200320000 207151 12/22/2023 AK E-LINE CBL IRU 41-01 50283200880000 192109 11/16/2023 AK E-LINE Perf KBU 22-06Y 50133206500000 215044 1/16/2024 AK E-LINE GPT/Perf KTU 32-07H 50133205110000 202043 10/27/2023 AK E-LINE PPROF KU 3-06A 50133207160000 223112 1/12/2024 AK E-LINE CBL KU 21X-32 50133202040000 169100 12/8/2023 AK E-LINE JetCut MPU CFP-02 50029212580000 184242 3/9/2024 READ CaliperSurvey NCI A-18 50883201890000 223033 12/8/2023 AK E-LINE Perf/GPT NIA NK-18 50029224210000 193177 12/13/2023 AK E-LINE IPROF PTM P1-13 50029223720000 193074 12/9/2023 AK E-LINE Cement TBU M-11 50733205900000 210145 1/8/2024 AK E-LINE Perf TBU M-15 50733204220000 190109 2/7/2024 AK E-LINE GPT/Perf Please include current contact information if different from above. T38615 T38615 T38616 T38617 T38618 T38619 T38620 T38621 T38622 T38623 T38624 T38625 T38626 T38627 T38628 TBU M-11 50733205900000 210145 1/8/2024 AK E-LINE Perf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.15 11:38:35 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/25/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240125 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-12 50231200310000 207123 1/3/2024 Yellowjacket GPT-PERF HV B-13 50231200320000 207151 12/13/2023 Yellowjacket SCBL HV B-17 50231200490000 215189 1/4/2024 Yellowjacket GPT-PERF HV B-16A 50231200400100 222070 1/12/2024 Yellowjacket GPT-PERF KBU 22-06Y 50133206500000 215044 12/5/2023 Yellowjacket GPT-PERF KTU 43-6XRD2 50133203280200 205117 12/4/2023 YELLOWJACKET GPT-PERF KU 21X-32 50133202040000 169100 12/23/2023 AK E-Line CALIPER TBU M-11 50733205900000 210145 11/10/2023 AK E-Line PL/PERF Please include current contact information if different from above. T38451 T38452 T38453 T38454 T38455 T38456 T38457 T38458 1/31/2024 TBU M-11 50733205900000 210145 11/10/2023 AK E-Line PL/PERF Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.31 09:35:23 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 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 10,290 feet 4,066 & 4,750 feet true vertical 8,945 feet 6,929 feet Effective Depth measured 4,066 feet See schematic feet true vertical 3,824 feet See schematic feet Perforation depth Measured depth 3,024 - 3,856 feet True Vertical depth 2,842 - 3,615 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 3,002 (MD) 2,823 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Middle Kenai Gas 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: 16 323-517 Sr Pet Eng: 5,410psi 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. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A 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 N/A 0 Size 470 0 1860 0 2500 13-3/8" 8,940psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-145 50-733-20590-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River / Middle Kenai Gas Trading Bay Unit M-11 Plugs Junk measured Length measured TVD Production Liner 6,618 3,884 Casing Structural 6,240 7" 6,618 10,283 8,940 470 1,432 470Conductor Surface Intermediate 28" 4,760psi 5,020psi 6,240psi 1,432 1,420 Burst Collapse 2,260psi 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 1:25 pm, Jan 24, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.01.23 19:20:19 - 09'00' Dan Marlowe (1267) RBDMS JSB 013024 DSR-1/26/24 Updated by: JLL 01/10/24 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-3 3,024’ 3,038’ 2,842’ 2,854’ Open 01/09/24 A-5 3,133’ 3,139’ 2,938’ 2,944’ Open 01/09/24 A-6 3,282’ 3,302’ 3,073’ 3,092’ Open 11/11/23 A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” X- Profile 2946’ 2773’ 3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’ 5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’ 6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’ 6.692” 4.256” Magna Range Plug (Set 10/21/23) 4066’3824’ Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A3-A5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D-15 Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands D-7 Sands GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 1509’ 1494’ 2.867 3-1/2" SFO-1 12 Dome 865 12/1/2011 2 2408’ 2316’ 2.867 3-1/2" SFO-1 12 Dome 850 12/1/2011 3 2920' 2750’ 2.867 3-1/2" SFO-1 16 Orifice 12/1/2011 ISOLATED JEWELRY & PERFORATION DETAILS - PAGE 2 Updated by: JLL 01/10/24 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Isolated - Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Isolated 10/21/23 C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Isolated 10/21/23 D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Isolated 09/21/23 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Isolated 09/21/23 D-7 5,318’ 5,351’ 5,056’ 5,087’ 31’ Isolated 09/21/23 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Isolated 09/21/23 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Isolated 09/21/23 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Isolated 09/21/23 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Isolated - Completion Equipment Information Item Depth MD Depth TVD OD ID Isolation Packer 4072’3829’ 8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’ 7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” Plug (Set 9/21/23) 4750’4499’ 3.500” -- 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Well Name:MRF M-11 API #:50733205900000 Field:McArthur River Field Start Date:9/21/2023 Permit #:210145 Sundry #:323-517 End Date:1/9/2024 9/21/2023 10/21/2023 10/22/2023 10/23/2023 11/10/2023 11/11/2023 Daily Operations: RIH w/ 2-3/8" Perf Gun #1. Correlate & Perforate Interval: 3282' - 3302'. Good pressure response. Gas production rate increasing. Pooh. All shots fired. Standby for Ops to watch production trend. Ops had to replace the water pump off the test separator. Decision to standby overnight to see if Ops can get the well flowing. Activity Report Fish E-Line Toolstring Fish E-Line Toolstring Move bridge, hatch cover, rig up slickline. P/T to 2500 PSI, good. RIH W/ 2.76" G-Ring, hangs up at 3880', W/T, falls through, continue to 4800' KB, POOH. RIH @ 300 ft/m W/ 20' of 2 3/8 dummy guns, drift to 4800', saw nothing at 3880' POOH. RIH W/ 3 1/2 GS and AD-2 stop, set at 4752' KB, POOH.Z/,tͬϯϭͬϮ'^ĂŶĚtĞĂƚŚĞƌĨŽƌĚWĂĐŬŽīƉůƵŐnjĞƌŽĞĚĂƚƉůƵŐďŽƩŽŵ͕ƐĞƚĂƚϰϳϱϬΖ<͕WKK,͘Z/,tͬϯ 1/2 GS and A-Stop, set at 4748' KB, POOH. Rig down slickline, move unit to M-21. Set Magna range plug at 4066' MD. Stuck setting tool afterwards. Can't release. Pull out of weak point. Well Flowing w/ 1mm Gaslift. Well Flow Rates: 1mm gas, 160 bwpd. Rig up AK Eline (1/4" cable). PT PCE to 250 low and 2500 high PASS. RIH w/ Production Logging Tools. See shift at 2928' going into water. Lightly Tag Magna Range Plug at 4066' (on depth). Perform 30/60/90 fpm passes from Plug - 2900'. Perform 5 min stop counts 10' above/below each MSV Screen Sleeve. Additional stop counts at 3100', 3010' & 2990'. Perform final jewelry pass from Plug to surface. Run back in hole & log 10fpm up/down pass from 2935' to 3120'. Stop count at 2935' & 3120'. Pooh. Lay down for the night. Page 1 of 2 Well Name:MRF M-11 API #:50733205900000 Field:McArthur River Field Start Date:9/21/2023 Permit #:210145 Sundry #:323-517 End Date:1/9/2024 11/25/2023 11/26/2023 11/27/2023 1/8/2024 1/9/2024 Activity Report Daily Operations: PJSM and PTW. Warm up equipment MU and RIH w/ 14' 2-3/8" 6spf 60deg 10.5gm Perforate 3,024'-3,038'. POOH, all shots Įred No signiĮcant pressure change or rate change observed. MU and RIH w/ 6' 2-3/8" 6spf 60deg 10.5gm Perforate 3,133'-3,139'. POOH, all shots Įred No signiĮcant pressure change or rate change observed. Secure well and RD AK-E-line. RUN PT SURVEY, BAIL FILL FROM 3206'KB TO 3226'KB AK E-line on board 0900 hr PJSM spot equipment. Rehead and r/up. Lunch. Presure test 250L/2500H ok. rih w/ 2-3/8" X 14' gas gun 60deg phased loaded @ 6SPF. did take weight @ 2030' wlm p/up and pass back through w/ no issue. Correlate Make tie inpasses and confirm w/ town w/ 3' correction. worked wire while. Production gets well shoot ready. log back on depth and perf A-3 sand interval 3024' - 3038' with good indication of fire. Pooh w/ no issue inspected gun 11 shots fired out of like 84 investigate gun for issue. secure well and shut dn for the night BAIL FILL FROM 3227'KB TO 3284'KB - DISCOVER HEAVY METAL MARKS ON BAILER BOTTOM ATTEMPT TO GET IMPRESSION AT 3284'KB WHICH CAUSED METAL MARKS ON BAILER PREV Page 2 of 2 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240119 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# HV B-15 50231200390000 212132 10/21/2023 Yellowjacket GPT-PERF TBU M-5 50733204130000 189133 10/20/2023 AK E-Line PERF TBU M-11 50733205900000 210145 10/21/2023 AK E-Line PLUG/PLT Please include current contact information if different from above. T38435 T38436 T38467 1/24/2024 TBU M-11 50733205900000 210145 10/21/2023 AK E-Line PLUG/PLT Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.22 12:57:24 -09'00' 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: 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): 10,290'6,929' Casing Collapse Structural Conductor Surface 2,260psi Intermediate Production 4,760psi Liner 5,410psi 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: Karson Kozub Contact Email:kkozub@hilcorp.com Contact Phone:907-570-1801 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 8,940' See schematic See schematic CO 228A Operations Manager 6,618' Perforation Depth MD (ft): 3,198 - 6,392 6,618' 7" 2,997 - 6,056 10,283'3,884' 3-1/2" 6,240'9-5/8" 28" 13-3/8" 470' 1,432' MD 5,020psi 470' 1,420' 470' 1,432' Length Size Proposed Pools: L-80 TVD Burst 3,002' 6,240psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 210-145 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20590-00-00 Hilcorp Alaska, LLC AOGCC USE ONLY 8,940psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 9/25/2023 Subsequent Form Required: 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: Tubing Size: PRESENT WELL CONDITION SUMMARY Trading Bay Unit M-11 McArthur River Middle Kenai Gas Same 8,945' 6,929' 6,489' 2,059psi 6,950' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-517 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.09.11 13:54:48 - 08'00' Dan Marlowe (1267) By Grace Christianson at 10:17 am, Sep 12, 2023 SFD 9/13/2023 Perforate DSR-9/12/23BJM 9/14/23 10-404 *&: JLC 9/14/2023 09/15/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.15 07:46:08 -08'00' RBDMS JSB 091523 Perf Add Well: M-11 Well Name:M-11 API Number: 50-733-20590-00-00 Current Status:SI Gas Producer Permit to Drill Number:210-145 First Call Engineer:Karson Kozub (907) 570-1801 (c) Leg B-2 (NE Corner) Second Call Engineer:Ryan Rupert (907) 301-1736 (c) Maximum Expected BHP:2,665 psi @ 6,056’ TVD 0.44psi/ft to deepest open pay Max. Potential Surface Pressure:2,059 psi Using 0.1 psi/ft Brief Well Summary: Well M-11 is a gas well completed in the A, B, C, and D Sands. M-11 has watered up and will not sustain flow. This program will temporarily isolate the D-2 and deeper sands to see if the upper sands will flow. Depending on the flow test we will then perforate additional sands below the upper packer. All proposed perfs remain within the Middle Kenai Gas Pool Pertinent wellbore information: - SSSV: Tubing retrievable (functional) - Multiple fish in the well up as high as 5,823’ - Inclination: o Less than 33 degrees to ~6000’ MD - 6/27/2021 o Slickline RIH with 2.5” LIB to 5,823’, E-line wire impressions Pre-Sundry work - Slickline runs as needed to evaluate wellbore - Set retrievable plug at ±4,800’ (Top of D-2 is 4,827’) - Flow upper sands E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500psi high 3. RIH and perforate Middle Kenai sands from ±3,002’ – ±4,800’ MD (±2,822 – ±4,548’ TVD) per RE/Geo a. * other E-line logs may be run as needed to evaluate wellbore 4. RDMO EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic within the Middle Kenai Gas Pool All proposed perfs remain Updated by: JLL 11/15/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-7 5,318’ 5,351’ 5,056’ 5,087’ 31’ Open 10/20/21 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D-15 Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands D-7 Sands Updated by: JLL 09/09/23 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 PROPOSED Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A –C ±3,002’ ±4,800’ ±2,822’ ±4,548’ Proposed Future A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-7 5,318’ 5,351’ 5,056’ 5,087’ 31’ Open 10/20/21 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’2822’8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D-15 Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands D-7 Sands Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/19/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL 7%U M-11 (PTD 210-145) Perf 10/20/2021 Please include current contact information if different from above. 37' (6HW 1DPHRQWUDQVPLWWDOFKDQJHGIURP0580WR 7%80$EE\%HOO Received By: 11/22/2021 By Abby Bell at 12:38 pm, Nov 22, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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 10,290 feet 6,950 feet true vertical 8,945 feet 6,929 feet Effective Depth measured 6,929 feet See schematic feet true vertical 6,489 feet See schematic feet Perforation depth Measured depth 3,198 - 6,392 feet True Vertical depth 2,997 - 6,056 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,002 MD 2,823 TVD Packers and SSSV (type, measured and true vertical depth)See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Name: Contact Email: Authorized Title:Contact Phone: 321-443 Sr Pet Eng: 5,410psi Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 18 8,940psi Katherine O'Connor Katherine.oconnor@hilcorp.com (907) 777-8376Dan Marlowe - Operations Manager measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0160 0 22 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 470' 1,432' N/A 35 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-145 50-733-20590-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River Field / Middle Kenai Gas Pool 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Trading Bay Unit M-11 Hilcorp Alaska, LLC Other: ______________________ measuredPlugs Junk measured N/A Length 470' 1,432' Size Conductor Surface Intermediate 28" 13-3/8" Production Liner 6,618' 3,884' Casing 470' 1,420' 6,240' 7" 6,618' 10,283' 8,940' 9-5/8"4,760psi 5,020psi 6,240psi Burst Collapse 2,260psi L G Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 1:44 pm, Nov 16, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.16 13:23:20 -09'00' Dan Marlowe (1267) DSR-11/16/21 RBDMS HEW 11/16/2021 BJM 11/17/21 SFD 11/18/2021 Updated by: JLL 11/15/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-7 5,318’ 5,351’ 5,056’ 5,087’ 31’ Open 10/20/21 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D-15 Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands D-7 Sands D-7 5,318’ 5,351’ 5,056’ 5,087’ 31’ Open 10/20/21 Rig Start Date End Date E-Line 10/20/21 10/20/21 10/20/2021 - Wednesday SIMops meeting w/ Production. PJSM & permit. Spot ELU, grease skid & toolbox on SW corner of drill deck. Inspect O- rings on all lubricator Bowen connections. MU lubricator. Rehead & check flow tubes. MU GR/CCL & Firing Head tool suite. Surface test GR/CCL. Fire check Firing Head. PU Perf Gun #1: 2-3/8" x 20' Razor HSC, 5spf, 60* phase, 10.8gm charges. CCL-to-Top Shot = 9.1'. Move to well. PT WLV & Lub = 250/1500 - PASS. Initial T/IA/OA = 156/30/190 Shut-in. RIH w/ Perf Gun #1 to 5467' CCL. Log up for correlation pass to 5135' CCL. Correct +1'. Send correlation pass files for review & verification of correction. No correction. RBIH to 5465' CCL. Log up to 5321.9' CCL to put shots on depth (5321.9' + 9.1' = 5,331' Top Shot). Fire Perf Gun #1 to perforate Zone D7 5,331' - 5,351'. Log up 200' & POOH. Initial T/IA/OA = 156/30/190 Shut-in. Open up well to shoot: FP 30/30/190. Perf gun #1 - All shots fired about 1oz of water in the bullplug. Shut well back in. MU Perf gun#2. RIH w/ Perf Gun #2 to 5310' CCL. Log up for correlation pass to 5130' CCL. Could not get bottom of guns past 5,331'. Send correlation pass files for review & discuss shot depths with RE. Correct -2'. RBIH to 5308' CCL. Log up to 5308' CCL to put shots on depth (5308' + 10' = 5,318' Top Shot). Fire Perf Gun #2 to perforate Zone D7 5,318' - 5,330'. Log up 200' & POOH. Initial T/IA/OA = 157/30/190 Shut-in. Open up well to shoot: Final Pressure 30/30/190. Perf gun #2 - All shots fired about 1oz of water in the bullplug. RD ELU. Turnover well to Production. Fly Eline crew to King Salmon. ELU Zone D7 Perf Add Job Complete. Final T/IA/OA = 9/130/195 Flow Rate 0MCFD. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20590-00 210-145 Well Name M-11 Fire Perf Gun #2 to perforate Zone D7 5,318' - 5,330'. L Fire Perf Gun #1 to perforate Zone D7 5,331' - 5,351' 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: ______________________ 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 10,290 feet 6,950 feet true vertical 8,945 feet 6,929 feet Effective Depth measured 6,929 feet See schematic feet true vertical 6,489 feet See schematic feet Perforation depth Measured depth 3,198 - 6,992 feet True Vertical depth 2,997 - 6,539 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,002 MD 2,823 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,940psi Daniel E. Marlowe Operations Manager Burst Collapse Katherine O'Connor katherine.Oconnor@hilcorp.com Tubing Pressure 2,260psi5,020psi 907 777-8376 6,240psi 470 1,420 6,240 8,940 470 1,432 Conductor Surface 5,410psi 4,760psi 28" 13-3/8" 6,618 Size 35 Production Casing Structural Liner 3,884 Length Intermediate N/A Junk 5. Permit to Drill Number: 0 McArthur River Field / Middle Kenai Gas PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 250 N/A Oil-Bbl 0 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-353 23 Authorized Signature with date: Authorized Name: 0 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-145 50-733-20590-00-00 Plugs ADL0018730 Trading Bay Unit M-11 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 13457 Casing Pressure 7" 6,618 MD 470 1,432 10,283 TVD measured true vertical Packer 9-5/8" PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:38 pm, Sep 07, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.07 14:33:29 -08'00' Dan Marlowe (1267) DSR-9/7/21 RBDMS HEW 9/7/2021 BJM 10/26/21 Updated by: JLL 09/01/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21pSchematic missing addperf interval 4805'-4810' md - bjm Updated by: JLL 09/21/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF) Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,805’ 4,810’ 4,553’ 4,558’ 5’ Open 08/19/21 D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’ 3.960” 2.813” Comp II "HP" Packer 3002’ 2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1) CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’ 3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’ 5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2) OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’ 3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’ 6.692” 4.256’ MSV Screen Sleeve (#3) CLOSED 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4) OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’ 6.692” 4.256” Isolation Packer 4072’ 3829’ 8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5) OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’ 7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E Sands TTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9 @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands Rig Start Date End Date E-Line 8/7/21 8/19/21 PTSM, Unstring coil from lubricator, break down eq. hook ups. N/D BOPE & riser f/M-09. Pull W/L bridge, install hatch covers, pull hatch cover from SW leg room, install W/L Bridge, spot ops cab, coil reel, power pack, BOPE, N2 pump & tank. Run pump & flow back lines, data cables , hydraulic lines & electric power lines. Test BOPE per Hilcorp & AOGCC specifications & standards. Witness waived on sundry approval by Jeremy Price, 7/28/21. Test BOPE to 250 / 3000 psi. BOPE Test Report submitted to AOGCC & copy saved to M-11 Project file on O drive. MU CTC & stab pipe. SDFN. Job in Progress. 08/13/2021 - Friday 08/07/2021 - Saturday Simops meeting w/ Production. PJSM & permit. Waiting on ELine crew to arrive on 08:30 helicopter. Crane crew clearing SW corner of platform to allow for ELU rig up. SW corner clear & prepped for ELU rig up. Eline crew arrives platform. PJSM & permit. Spot ELU, grease skid & toolbox on SW corner of drill deck. Lift SW well hatch & install bridge. Only able to find 25' of 3-1/2" lubricator on the platform, 10' short of lubricator to cover 32' perf gun tool suite. Fly out two 5' sections of 3-1/2" lubricator from beach. Wait on helicopter green deck. Continue ELU RU. Install new O- rings on all lubricator bowen connections. MU lubricator. Rehead & install new flow tubes. MU GR/CCL & Firing Head tool suite. Surface test GR/CCL. Fire check Firing Head. PU Perf Gun #1: 2-3/8" x 17' Razor HSC, 6 spf, 60* phase, 10.8 gm charges. CCL-to-Top Shot = 11.9'. Move to well. PT WLV & Lub = 250/1500 - PASS. Release crane operator to CTU crew. Initial T/IA/OA =125/125/195. RIH w/ Perf Gun #1 to 5220' CCL. Log up for correlation pass to 4800' CCL. Correct +0.50'. Send correlation pass files for review & verification of correction. Correct +2.0'. RBIH to 5225' CCL. Log up to 4985.1' CCL to put shots on depth (4985.1' + 11.9' = 4997' Top Shot). Fire Perf Gun #1 to perforate Zone D3 4997' - 5014'. Log up 200' & POOH. OOH w/ all shots fired & dry gun. RD ELU. Fly bridge to M-09 NE corner well hatch & install M-11 SW corner well hatch. Turnover well to Production. Fly Eline crew to beach. ELU Zone D3 Perf Add Job Complete. Final T/IA/OA = 125/130/195. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20590-00 210-145 Well Name M-11 Test BOPE to 250 / 3000 psi. Fire Perf Gun #1 to perforate Zone D3 4997' - 5014'. Rig Start Date End Date E-Line 8/7/21 8/19/21 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20590-00 210-145 Well Name M-11 08/19/2021 - Thursday PJSM & permit. Rig ELU off M-14. Spot wireline bridge over M-11. RU ELU. Strip & cut xxx' of cable & rehead rope socket. MU GR/CCL toolsuite. Surface test GR/CCL. Fire check Firing Head. PU Perf Gun #1: 2-3/8" x 20'' Razor Low Swell, 5 spf, 60 deg, 11 gm. CCL-to-Top Shot = 6.8'. Move to well. PT WLV & Lub = 250/1500. Tubing = 15, FR = 0. RIH w/ Perf Gun #1 to 5212' CCL. Log up to 4300' CCL. Send log for review. Correct -1.0'. RBIH to 4943'CCL. Log up to 4839.2' CCl to put shoots on depth (4839.2 + 6.8 = 4846' TS). Fire Perf Gun #1 to perf Zone D2 4846' - 4866'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. Tubing = 17, FR = 0. PU Perf Gun #2: 2-3/8" x 19'' Razor Low Swell, 5 spf, 60 deg, 11 gm. CCL-to-Top Shot = 7.5'. RIH w/ Perf Gun #2 to 5200' CCL. Log up to 4473' CCL. Correct +0.20'. Send log for review. RBIH to 4888'CCL. Log up to 4819.5' CCl to put shots on depth (4819.5 + 7.5 = 4827' TS). Fire PG #2 to perf Zone D2 4827' - 4846'. Log up 200' & POOH. OOH all shots fired & dry. Surface test GR/CCL & fire check FH. Tubing = 16, FR = 0. PU Perf Gun #3: 2-3/8" x 5'' Razor Low Swell, 5 spf, 60 deg, 11 gm. CCL-to-Top Shot = 19.5.' RIH w/ PG #3 to 5200' CCL. Log up to 4493' CCL. Correct +8.0'. Send log for review. RBIH to 4893' CCL. Log up to 4785.5' CCl to put shoots on depth (4785.5 + 19.5 = 4805' TS). Fire PG #3 to perf Zone D Upper 4805' - 4810'. Log up 200' & POOH. OOH all shots fired & dry. Tubing = 12, FR = 0. Turnover well to Production. RD ELU prepping all loads for backload to next day rope/soap/dope boat. Secure & clean drill deck & upper well room. Fly crew to beach. Job Complete. 08/14/2021 - Saturday Simops meeting w/ Production. PJSM & permit. Complete CTU rig up. PU injector & MU1.75" slim jet nozzle BHA. Move to well. PT BOP/LUB = 3500. Open swab(20T). T = 35 psi. RIH w/ 1.75" jet nozzle. Production lines out to take returns to test separator & flair. 3500' Bring on N2 pump = 300 scfm & continue RIH circulating N2. All returns to test separator & flair. T = 6, CTP = 460. RIH to 5500', T= 7 & CTP = 937. Increase N2 = 00 scfm & PUH slowly. Gain fluid returns to test separator. PUH to 4900'. Cycle 4900' - 5100' w/ N2 = 400 scfm. 4 bbl fluid returned to test separator, Flow = 1.6 MM/day. T = 55 & CTP = 1000. Continue to cycle 4900' - 5100', 6 bbl fluid to separator & Flow = 0.9 MM/day. Inc N2 = 500 scfm. Well is slugging 0.75 - 1.5 MM/day. CTP pressure inc =1300. RIH from 5100' to tag @ 6117', work pipe & unable to pass. T= 9 & CTP = 2000, inc. N2 = 700. PUH. 12 bbl total to test separator. Flow = 0.300 MM/day. PUH to 4950' & park coil. T = 84 psi. Flow = 2.8 MM/day & dry. No fluid @ test separator. Decrease N2 = 300 scfm. Hold in hole & lift w/ N2 @ 300 scfm to assist well. Flow rate falls back and surges 0.50 - 1.6 MM/day. N2 = 300 scfm. Well flowing 0.6 - 1.0 MM/day w/ T = 22 & CTP = 750. Returns are all N2 & gas, no water. N2 tank 95% empty. Shut down N2 & POOH. OOH w/ well not flowing. Close swab & bleed off pressures. Turnover well to production. Rig down CTU while backloading to M/V Masco. Backload N2 pump & tank, batch mixer, generator, power pack, console, choke, lubricator box, down toolbox & reel. M/V Masco away from platform returning to dock. Complete CTU package rig down prepping all loads for backload to boat. Coil crew & crane operator resting while waiting on 2nd boat. M/V Masco arrives platform. Crane operator & coil crew back on tour. Backload remainder of CTU package to boat. Crew resting. Fly out to beach. CTU N2 Lift Job Complete. Fire Perf Gun #1 to perf Zone D2 4846' - 4866'. Fire PG #3 to perf Zone D Upper 4805' - 4810'.This interval was missing from the diagram. Fire PG #2 to perf Zone D2 4827' - 4846' 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: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,290'6,929' Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 5,410 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.Oconnor@hilcorp.com Contact Phone: (907) 777-8376 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 8,945' 6,929' 6,489' 605 psi 3,884' 7" 6,240'9-5/8" 10,283' 8,940' 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. 9/16/2021 3-1/2" Daniel E. Marlowe See Schematic 6,618' Perforation Depth MD (ft): 3,198 - 6,992 6,618' See Schematic Tubing Grade:Tubing MD (ft): 2,997 - 6,539 Perforation Depth TVD (ft): 28" 13-3/8" 470' 1,432' 470' 1,420' 470' 1,432' 9.2 # / L-80 TVD Burst 3,002' 6,240 psi 8,940 psi Tubing Size: MD 5,020 psi 210-145 50-733-20590-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 228A Trading Bay Unit M-11 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 6,950' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:15 pm, Sep 02, 2021 321-443 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.02 11:29:19 -08'00' Dan Marlowe (1267) DSR-9/2/21SFD 9/2/2021 10-404 BJM 9/9/21 dts 9/9/2021 JLC 9/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.10 15:18:19 -08'00' RBDMS HEW 9/13/2021 Well Work Prognosis Well Name:Trading Bay Unit M-11 API Number: 50-733-20590-00-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:9/16/21 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:210-145 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:1,048 psi @ 4,420’ TVD 0.237 psi/ft base off M-22 RFT data 2018 Maximum Expected BHP:1,048 psi @ 4,420’ TVD 0.237 psi/ft base off M-22 RFT data 2018 Maximum Potential Surface Pressure:605 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: Well M-11 is a gas well completed in the A, B, C, and D Sands. This well was recently perforated in the D-3 sands in 2020. M-11 has recently watered up. In August 2020 perforations were added into the D2 and D3 sands, and the well was lifted with N2 but would still not flow. This program is to add perforations in the D-7 sands. E-line Procedure: 1. MIRU E-line, PT lubricator to 250 psi low/ 1,500psi high. 2. Perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 09/01/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands Updated by: JLL 09/02/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 PROPOSED Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 4,827’ 4,866’ 4,574’ 4,612’ 39’ Open 08/19/21 D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/07/21 D-7 ±5,319’ ±5,351’ ±5,056’ ±5,087’ ±32’ Proposed Future D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G 05 9 830’9 868’8 613’8 641’5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D-15 Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands D-7 Sands David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 08/25/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: TBU M-1 Perf (PTD 21) FTP Folder Contents: Log Print Files and LAS Data Files: Please include current contact information if different from above. 37' (6HW eceived By: 08/30/2021 By Abby Bell at 3:32 pm, Aug 25, 2021 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,290'6,929' Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 5,410 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:kkozub@hilcorp.com Contact Phone: (907) 570-1801 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Karson Kozub PRESENT WELL CONDITION SUMMARY Length Size 6,950' COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 210-145 50-733-20590-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 228A Trading Bay Unit M-11 9.2 # / L-80 TVD Burst 3,002' 6,240 psi 8,940 psi Tubing Size: MD 5,020 psi 470' 1,420' 470' 1,432' 28" 13-3/8" 470' 1,432' 6,618' Perforation Depth MD (ft): 3,198 - 6,992 6,618' See Schematic Tubing Grade:Tubing MD (ft): 2,997 - 6,539 Perforation Depth TVD (ft): 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. 8/5/2021 3-1/2" Daniel E. Marlowe See Schematic 8,945'6,929'6,489'605 psi 3,884'7" 6,240'9-5/8" 10,283'8,940' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 8:14 am, Jul 19, 2021 321-353 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.07.16 16:00:02 -08'00' Dan Marlowe (1267) X DSR-7/19/21DLB 07/19/2021 CT X 10-404 CT BOP test to 3000 psi. Witness not required if it is Schlumberger CT. BJM 7/27/21 dts 7/28/2021 JLC 7/28/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.28 15:57:59 -08'00' RBDMS HEW 7/30/2021 Well Work Prognosis Well Name:Trading Bay Unit M-11 API Number: 50-733-20590-00-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:8/5/2021 Rig:E-Line, Coil Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:210-145 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:1,048 psi @ 4,420’ TVD 0.237 psi/ft base off M-22 RFT data 2018 Maximum Expected BHP:1,048 psi @ 4,420’ TVD 0.237 psi/ft base off M-22 RFT data 2018 Maximum Potential Surface Pressure:605 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: Well M-11 is a gas well completed in the A, B, C, and D Sands. This well was recently perforated in the D-3 sands in 2020. M-11 has recently watered up. This program is to re-perforate the D-3 sands, add perforations in the D-2 sands and nitrogen lift the well if it does not flow on its own. E-line Procedure: 1. MIRU E-line, PT lubricator to 250 psi low/ 1,500psi high. 2. Perforate with well flowing per program. 3. RD E-line. 4. * Contingent N2 lift if the well does not flow on its own a. RU Coil tubing b. Test BOPE’s to 250psi low/3,000psi high (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). c. RIH just above the tubing tail ±2,970’ d.Blow the well dry with Nitrogen to production header 5. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil BOP drawing 4. Standard Well Procedure – Nitrogen Operations 5. Flow Diagrams Updated by: JLL 09/14/20 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/27/20 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’ 3.960” 2.813” Comp II "HP" Packer 3002’ 2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’8.310” 3.830” GP Sleeve 3260’ 3053’ 5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’ 6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’ 6.692” 4.256” Isolation Packer 4072’3829’ 8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’ 7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Updated by: JLL 07/14/21 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 PROPOSED Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 Upr ±4,805’ ±4,810’ ±4,553’ ±4,558’ ±5’ Proposed Future D-2 ±4,827’ ±4,866’ ±4,574’ ±4,612’ ±39’ Proposed Future D-3 ±4,997’ ±5,014’ ±4,741’ ±4,758’ ±17’ Proposed Re-Perf Future D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Isolated 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Completion Equipment Information Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" Wellstar TRSV, SN – 101073690 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’ 3.960” 2.813” Comp II "HP" Packer 3002’2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’ 5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’ 6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’ 3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’ 6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’ 7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D-2 Sands Coiled Tubing BOP 05/21/2020 SWAB VALVE MASTER VALVE Hilcorp Flow DiagramFluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review 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 Nitrogen Tank. 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 supplier 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 Tank. 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: ______________________ 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 10,290 feet 6,950 feet true vertical 8,945 feet 6,929 feet Effective Depth measured 6,929 feet See schematic feet true vertical 6,489 feet See schematic feet Perforation depth Measured depth 3,198 - 6,992 feet True Vertical depth 2,997 - 6,539 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,002 MD 2,823 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 9-5/8" 7" 6,618 MD 470 1,432 10,283 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 11100 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-145 50-733-20590-00-00 Plugs ADL0018730 Trading Bay Unit M-11 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-327 724 Authorized Signature with date: Authorized Name: 13 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 268 N/A Oil-Bbl 481 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 4,939 McArthur River Field / Middle Kenai Gas PoolN/A measured 6,618 Size 420 Production Casing Structural Liner 3,884 Length 470 1,432 Conductor Surface 5,410psi 4,760psi 28" 13-3/8" 907 777-8376 6,240psi 470 1,420 6,240 8,940 Collapse Katherine O'Connor katherine.Oconnor@hilcorp.com Tubing Pressure 2,260psi5,020psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,940psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:48 am, Sep 18, 2020 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Date: 2020.09.17 16:01:55 -05'00' Daniel Marlowe DSR-9/18/2020gls 9 28/20 Perforate 4,939 RBDMS HEW 9/18/2020 Updated by: JLL 09/14/20 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/27/20 D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’ 2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’ 8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-3 Sands D Sands D-16 Sands 08/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161’ 8/28/20 750’ ¼” wire & 32.4’ wireline tools at ±6,161 ’ D-3 Sands D-3 4,997’ 5,014’ 4,741’ 4,758’ 17’ Open 08/27/20 new perfs 4997-5014 ft Rig Start Date End Date E-Line 8/27/20 8/28/20 08/27/20 - Thursday Mobe e-line crew t/platform, orientate & PJSM while waiting for ops to fix an issue with compressor. R/U on M-11, p/u lubricator, m/u GR,CCL, Gun #1 =17' 2 3/8" carrier w/10.8 gram Razor low Swell charges 60deg phasing 6 SPF. PT lubricator and WLV to 250/1500, tested good. RIH. @ 4200' could not make it past wireline tubes. Found bad spot on wire. POOH to cut 4200' of wire. At surface, swab shut, bleed down , pop off well. Start cutting wire. 4200' wire cut, tools made back up, wire tested good, stab on well. Open up, RIH to 5220' log up to 4800', send log in for approval to shoot D3 sands 4997'-5014' Got approval (Geologist). RIH & log up t/ CCL depth 4985', CCL t/top shot 12', CCL t/btm shot 29' 12 psi ITP flowing @ .9, Shoot 4997'-5014', change in Pressure and flow, FTP 650 psi. 4.7mm rate log up 200'. POOH, @ 759' it appears we were blow up hole. We can not move wire up or down. PJSM with production to remove wire from well. Tried to cycle wireline valves so we can bleed off above valves. Could not get valves to seal. Decision made to stand by till morning for plan forward. 08/28/20 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20590-00 210-145 Well Name M-11 PJSM & Permit signed. Still can't move wire up or down, try to shut SSSV, no success. Decision made to cut wire with Swab valve. Shut swab valve on wire, cutting eline wire. Shut in master open swab to bleed pressure off between the two valves. Pop off Eline, isolate well. Lay down lubricator start pulling wire out of grease head. Had multiple kinks about every 1' on the wire. Get Eline rigged down. Getting slickline headed out. Slickline arrive on Platform. PJSM & permits signed. MIRU slickline. Stab on well, pt lubricator/ wlv, 250/1500 psi. 2.73" LIB. RIH tag fish at 6165' rkb. Ooh had small impression of wire on lib. Swab out tools, put on 2.72" X 2' wire grab on, rih set down at same. Got two jar hits and sheared pulling tool. OOH put steal pin in. RIH latch into fish @ 6165' rkb, work wire was able to get wire grab to slip off. Pooh, wire grab recovered. Make up 2.73" LIB, rih for tag. Tag at 6161' RKB. POOH, OOH pop off well. Light impression of wire on LIB. 750' 1/4" wire, 32.4' wireline tools left in hole. RDMO send slickline crew to the beach. 4.7mm rate log up 200'. POOH, @ 759' it appears we were blow up hole. Wire and fish left in hole . , Shoot 4997'-5014', blown uphole .... . RIH tag fish at 6165' 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: ______________________ 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 10,290 feet 6,950 feet true vertical 8,945 feet 6,929 feet Effective Depth measured 6,929 feet See schematic feet true vertical 6,489 feet See schematic feet Perforation depth Measured depth 3,198 - 6,992 feet True Vertical depth 2,997 - 6,539 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# / L-80 3,002 MD 2,823 TVD Packers and SSSV (type, measured and true vertical depth)See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 9-5/8" 7" 6,618 MD 470 1,432 10,283 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 11109 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 210-145 50-733-20590-00-00 Plugs ADL0018730 Trading Bay Unit M-11 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-133 10 Authorized Signature with date: Authorized Name: 100 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 256 N/A Oil-Bbl 503 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 430 McArthur River Field / Middle Kenai Gas PoolN/A measured 6,618 Size 264 Production Casing Structural Liner 3,884 Length 470 1,432 Conductor Surface 5,410psi 4,760psi 28" 13-3/8" 907 777-8376 6,240psi 470 1,420 6,240 8,940 Collapse Katherine O'Connor katherine.Oconnor@hilcorp.com Tubing Pressure 2,260psi5,020psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,940psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 6:37 pm, Aug 06, 2020 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Date: 2020.08.06 14:29:21 -08'00' Daniel Marlowe SFD 8/10/20 SFD 8/10/2020RBDMS HEW 8/7/2020 gls 9/8/20 DSR-8/7/2020 Updated by: JLL 08/05/20 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’ 2822’8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D Sands D-16 Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 D-16 9 Rig Start Date End Date E-Line 7/27/20 7/27/20 07/27/20 - Monday Mobe e-line crew t/platform. Orientate & PJSM while waiting for gear & tools on next chopper. R/U on M-11. P/u lubricator, m/u GR,CCL, gun =20' 2 3/8" carrier w/11 gram Razor low Swell charges 60deg phasing 6 SPF. PT lubricator 250/1500 repair leaks as needed, tested good. RIH t/6564', log up t/6100', send logs to town for correlation adjustments, adjust 4' as requested resend log, approved by Geologist to shoot 6372'-6292'. RIH & log up t/ CCL depth 6364.7', CCL t/top shot 7.3', CCL t/btm shot 27.3' 12 psi ITP flowing @ .9. Shoot 6372'-6392', no change in Pressure or flow, FTP 12 psi. log up 200', POOH. Shut in well bleed off RDMO all shots fired. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20590-00 210-145 Well Name M-11 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: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 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): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,290'6,929' Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 5,410 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 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 8,945' 6,929' 6,489' 808 psi 3,884' 7" 6,240'9-5/8" 10,283' 8,940' 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. 8/22/2020 3-1/2" Daniel E. Marlowe See Schematic 6,618' Perforation Depth MD (ft): 3,198 - 6,992 6,618' See Schematic Tubing Grade:Tubing MD (ft): 2,997 - 6,539 Perforation Depth TVD (ft): 28" 13-3/8" 470' 1,432' MD 5,020 psi 470' 1,420' 470' 1,432' 9.2 # / L-80 TVD Burst 3,002' 6,240 psi 8,940 psi Tubing Size: 210-145 50-733-20590-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 228A Trading Bay Unit M-11 COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 6,950' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 10:40 am, Aug 07, 2020 320-327 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.07 10:14:47 -08'00' Dan Marlowe (1267) X SDR-8/7/2020 Perforate GAS 10-404 gls 8/20/20 DLB 08/07/2020dts 8/20/2020 8/21/2020Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.21 08:33:29 -08'00' RBDMS HEW 8/24/2020 Well Work Prognosis Well Name:Trading Bay Unit M-11 API Number: 50-733-20590-00-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:8/22/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:210-145 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Cell: 907-570-1801 Current Bottom Hole Pressure:250 psi @ 5,900 TVD 0.042 psi/ft gradient Maximum Expected BHP:1398 psi @ 5,900’ TVD 0.237 psi/ft water gradient to surface Maximum Potential Surface Pressure:808 psi @ 2,997’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: Well M-11 is a gas well completed in the A, B, C, D, and E Sands. This well was recently perforated in the D-16 sand. This program objective is to go in and add additional perforations uphole, into the D-2 and D-3 sands. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. Perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 08/05/20 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 SCHEMATIC Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’ 2822’8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D Sands D-16 Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’ Updated by: JLL 08/07/20 Steelhead Well M-11 As Completed: 12/07/2011 PTD: 210-145 / API: 50-733-20590-00 PROPOSED Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-2 ±4,805’ ±4,810’ ±4,553’ ±4,558’ ±5’ Proposed Future D-2 ±4,827’ ±4,866’ ±4,574’ ±4,612’ ±39’ Proposed Future D-3 ±4,997’ ±5,014’ ±4,741’ ±4,758’ ±17’ Proposed Future D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 6,372’ 6,392’ 6,039’ 6,056’ 20’ Open 07/27/20 E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID Tubing Hanger 73.24’ 13.440” 2.940” 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’3.960” 2.813” Comp II "HP" Packer 3002’ 2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve (#1)CLOSED 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’8.310” 3.830” GP Sleeve 3260’ 3053’5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve (#2)OPEN 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’6.692” 4.256’ MSV Screen Sleeve (#3)CLOSED 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve (#4)OPEN 4050' 3807’6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’6.692” 4.256” Isolation Packer 4072’3829’ 8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve (#5)OPEN 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5 Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD RKB: 73.24’; RKB to MSL: 160’; RKB to Mudline: 345’ 04/08/20 26.5’ toolstring at ±6,500’D-2 Sands D-3 Sands D Sands D-16 Sands new perf 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: Exploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 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): McArthur River Field / Middle Kenai Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,290'6,929' Casing Collapse Structural Conductor Surface 2,260 psi Intermediate Production 4,760 psi Liner 5,410 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:mmckinley@hilcorp.com Contact Phone: (907) 777-8387 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 8,945' 6,929' 6,489' 998 psi 3,884' 7" 6,240'9-5/8" 10,283' 8,940' 8,940 psi 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. 4/15/2020 3-1/2" Daniel E. Marlowe See Schematic 6,618' Perforation Depth MD (ft): 3,198 - 6,992 6,618' See Schematic 28" 13-3/8" 470' 1,432'5,020 psi 470' 1,420' 470' 1,432' Trading Bay Unit M-11 6,950' 9.2 # / L-80 TVD Burst 3,002' 6,240 psi MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 210-145 50-733-20590-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC CO 228A Tubing Grade: Tubing MD (ft): 2,997 - 6,539 Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size COMMISSION USE ONLY Authorized Name: Authorized Signature: Operations Manager Mark McKinley Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Daniel Marlowe I am approving this document 2020.03.25 14:38:58 -08'00' Daniel Marlowe By Jody Colombie at 3:49 pm, Mar 25, 2020 320-133 SFD 3/25/2020gls 3/26/20 10-404 DSR-3/25/2020GWV Required? Yes No Com m. 3/26/2020 JLC 3/26/2020 Well Work Prognosis Well Name:Trading Bay Unit M-11 API Number: 50-733-20590-00-00 Current Status:Gas Well Leg:B-2 (NE corner) Estimated Start Date:4/15/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:210-145 First Call Engineer:Mark McKinley Office: 907-777-8387 Cell: 907-953-2685 Second Call Engineer:Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current Bottom Hole Pressure:250 psi @ 5,900 TVD 0.042 psi/ft gradient Maximum Expected BHP:2,555 psi @ 5,900’ TVD 0.433 psi/ft water gradient to surface Maximum Potential Surface Pressure:998 psi @ 2,997’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) **Well to be perforated while flowing Brief Well Summary: Well M-11 is a gas well completed in the A, B, C, D, and E Sands. This project will Re-Perf in the A-5C sand and add additional perforations in the D-16 Sand. A-5C sands are behind a gravel pack screen assembly with a closed and seized up MSV Screen Sleeve, we will be shooting through this assembly to regain access to the isolated sands. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 11/13/15 Steelhead Well M-11 As Completed: 12/07/2011SCHEMATIC Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C 3,198’ 3,205’ 2,997’ 3,003’ 14 Open A-5C 3,214’ 3,234’ 3,011’ 3,029’ 14 Open B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’ 3.960” 2.813” Comp II "HP" Packer 3002’ 2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’ 5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’ 6.692” 4.256’ MSV Screen Sleeve 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’ 6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’ 7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5C Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D Sands Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop - ~4,198’ SLM 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD Updated by: JLL 03/10/20 Steelhead Well M-11 As Completed: 12/07/2011PROPOSED Completion Equipment Information Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Density (SPF)Status Date, Comment A-5C ±3,198’ ±3,205’ ±2,997’ ±3,003’ ±14 Re-perf Future/Proposed A-5C ±3,214’ ±3,234’ ±3,011’ ±3,029’ ±14 Re-perf Future/Proposed B-3 3,549’ 3,620’ 3,321’ 3,388’ 14 Open B-5 3,810’ 3,848’ 3,571’ 3,608’ 14 Open B-5 3,852’ 3,856’ 3,611’ 3,615’ 14 Open B-8 4,032’ 4,054’ 3,790’ 3,811’ 14 Open C-1 4,135’ 4,140’ 3,891’ 3,896’ 14 Open C-1 4,143’ 4,180’ 3,899’ 3,935’ 14 Open D-15 6,239 6,244’ 5,923’ 5,928’ 6 Open 10/28/15 D-16 6,304’ 6,309’ 5,980’ 5,984’ 6 Open 10/27/15 D-16 ±6,371’ ±6,394’ ±6,037’ ±6,057’ ±23’ Future Proposed E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588’ 7,595’ 6,990’ 6,995’ 4 Isolated 12/20/2012 F-11 8,946’ 8,977’ 7,975’ 7,997’ 6 Isolated F-15B 9,270’ 9,290’ 8,209’ 8,223’ 6 Isolated F-16 9,420’ 9,440’ 8,317’ 8,331’ 6 Isolated G-05 9,830’ 9,868’ 8,613’ 8,641’ 5 Isolated Item Depth MD Depth TVD OD ID 3-1/2" 9.3# TC-II SCSSV 481’ 481’ 5.176” 2.813” 3 ½” SFO-1 Mandrel 1509’ 1494’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2408’ 2316’ 5.313” 2.867” 3 ½” SFO-1 Mandrel 2920' 2750’ 5.313” 2.867” 3 ½” X- Profile 2946’ 2773’ 3.960” 2.813” Comp II "HP" Packer 3002’ 2822’ 8.320” 6.000” GP Sleeve 3043’ 2858’ 5.880” 3.750” 5” Blank Pipe 3061’ 2874’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3179' 2979’ 6.692” 4.256” MSV Screen Sleeve 3231’ 3026’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3238' 3033’ 6.692” 4.256” Isolation Packer 3254’3047’ 8.310” 3.830” GP Sleeve 3260’ 3053’ 5.880” 3.750” 5” Blank Pipe 3277’ 3068’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3534' 3306’ 6.692” 4.256’ MSV Screen Sleeve 3617’ 3385’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3624’ 3392’ 6.692” 4.256’ Isolation Packer 3640’3407’ 8.310” 3.830” GP Sleeve 3645’ 3412’ 5.880” 3.750” 5” Blank Pipe 3663’ 3429’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 3789' 3550’ 6.692” 4.256’ MSV Screen Sleeve 3857’ 3616’ 6.692” 3.830’ 8 Ga Wire Wrapped Screen 3964’ 3722’ 6.692” 4.256’ Isolation Packer 3880’3639’ 8.310” 3.830” GP Sleeve 3886’ 3645’ 5.880” 3.750” 5” Blank Pipe 3903’ 3661’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4004’ 3762’ 6.692” 4.256” MSV Screen Sleeve 4050' 3807’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4057’ 3814’ 6.692” 4.256” Isolation Packer 4072’3829’8.310” 3.830” GP Sleeve 4078’ 3835’ 5.880” 3.750” 5” Blank Pipe 4096’ 3852’ 5.000” 4.276” 8 Ga Wire Wrapped Screen 4118’ 3874’ 6.692” 4.256” MSV Screen Sleeve 4171’ 3926’ 6.692” 3.830” 8 Ga Wire Wrapped Screen 4177’ 3932’ 6.692” 4.256” Comp-Perm II Sump Packer 4184’ 3939’ 8.125” 6.000” 7" 29# LTC- Casing 4188’ 3943’ 7.000” 6.184” 3-1/2" 9.3# TC-II Tubing 4219’ 3974’ 3.500” 2.992” 3 1/2 9.3# TC-II Half Muleshoe 6351’ 6020’ 3.500” 2.920” Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM (MD) BTM (TVD) 28” Structural 27” Surface 470’ 470’ 13-3/8” 68 L-80 BTC 12.415 Surface 1432’ 1420’ 9-5/8” 47 L-80 BTC-M 8.681 Surface 6618’ 6240’ 7” 26 L-80 DWC 6.276 6399’ 10283’ 8939’ 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002’ 2822’ TOC & Posi-Set #1 = 9,510’ 7” Liner in 8 ½” Hole TOC & Posi-Set #1 = 9,374’ TOC & Posi-Set #1 = 8,991’ Swell Packers @ 8,831’, 9,014’, 9,491’, 9,759’ 7” x 3 ½” FB-1 Packer 7” x 3 ½” S-3 Packer ECP Stage Collar 28” Conductor Comp II Pkr, 4 Iso Pkrs Comp II Sump Packer X Profile Cement Retainer @ 8,491’ TOC @ 8,286’ E-7 Sands Tagged Fill @ 8,274’ A-5C Sands B-3,B-5 Sands B-8 Sands C-1 Sands E SandsTTVBP @ 7,210’ Bridge Plug @ 6,950’ with 20’ cement TOC @ 6,929’ D Sands D-16 Fish: 10’ Titan 2-1/2” Strip Gun AD 2 Stop - ~4,198’ SLM 9 5/8” x 7” Liner Hanger w/ ZXP Liner Top Packer Stage Collar 13 3/8” Csg in 17 1/2” Hole 9 5/8” Csg in 12 ¼” Hole MAX HOLE ANGLE = 43.9q @ 7,689’ MD TD 10,290’MD/8,945’TVD PBTD 6,929’/6,489’TVD • 2\c7-1 J45 t Z� -1241 t Company HILCORP ALASKA, LLC Hilcora Alaska,LLC Well Name TBU M-11 RECEIVED Field Name McArthur River Unit OCT 2 5 2017 State Alaska AOGCC 111 API 50-733-20590-00-00 Schlumberger Logged by C. Bowker ' Logging Date 28-Aug-2017 Report Date 04-Sept-2017 SCANNED FEB 2 8 2018 Analysis By Divyani Mishra Production Services Platform .1 Production Log Interpretation Report t SIS I • • 1 INTERPRETATION SUMMARY 3 I 1.1 INTRODUCTION 3 1.2 OBJECTIVES 3 1.3 TECHNIQUE 3 2 DATA QUALITY AND INTERPRETATION COMMENTS 3 3 TABLE 1:COMPUTED PRODUCTION RATE AT STANDARD CONDITIONS 4 t 4 TABLE 2:COMPUTED PRODUCTION RATE AT RESERVOIR CONDITIONS 4 5 INTERPRETATION PROFILE:FLOWING SURVEY 5 6 BASIC SENSORS AND MATCH DATA:FLOWING SURVEY 6 I7 DEFT WATER HOLDUP DATA:FLOWING SURVEY 7 8 TABLE OF ABBREVIATIONS 8 I 9 WELL AND JOB DATA 9 9.1 WELL SCHEMATIC 9 9.2 SPINNER CALIBRATION:FLOWING SURVEY 10 U 9.3 TOOL STRING 11 30 APPENDIX Z:ZONE COLOR CODE 12 I I I I I I I I I I I I TBU M-11 Page 1 of 12 28/08/17 • • ' DISCLAIMER ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED ' BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER. ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANY SUCH INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES "AS IS", THAT SCHLUMBERGER MAKES NO REPRESENTATION OR WARRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT t NOT LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION ' TAKEN BASED ON THE SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF. 1 1 TBU M-11 Page 2 of 12 28/08/17 • • 1 Interpretation Summary 1.1 Introduction A production log was run in the TBU M-11 well on 28 Aug 2017 using PSP (Production Services Platform). 1.2 Objectives ' Production log was recorded in the TBU M-11 well with following objective: 1. Identify the major water entry contributing zone ' 2. Obtain Production Profile/Splits 1.3 Technique A 1 11/16" production logging tool was deployed on wireline. The wellbore has a maximum deviation ' of 35 deg over the logged interval. The sensors present are Casing Collar Locator, Pressure, Temperature, Gamma-Ray, PGMC (density), DEFT, PILS spinner and PFCS spinner. There are three up and three down passes logged at 40, 80 & 120 ft/min over the interval 2870 - 6550 ft. MD along with fifteen station stops at depths 6500 ft, 6368 ft, 6344 ft, 4130 ft, 4000 ft, 3800 ft, 3550 ft, ' 3191 ft, 2970 ft, 2870 ft, 2460 ft, 2360 ft, 1560 ft, 1460 ft, and 82 ft. MD at a production surface rate of 700 MCFD gas lift assist, 650 MCFD formation gas, and 600 BWPD. 2 Data Quality and Interpretation Comments ' In general, the data quality is good and consistent in between passes across the logging interval. The spinner data clearly identifies the fluid entry intervals. ' The spinner, temperature and holdup sensors capture the changes occurring across the logged interval due to the fluid entries. As per the DEFT data, first hydrocarbon entry was observed at around 3594 ft. MD during flowing survey. Based on the spinner, temperature and holdup responses, major water and gas entries were observed across the perforation interval 3214- 3234 ft. MD contributing - 85.68% of total production; also, minor water and gas entries were observed across the perforation intervals 3198- 3205 ft. MD and 3549- 3620 ft. MD contributing - 13.23% and - 1.09% ' of total production respectively. The perforations below 3810 ft. MD were observed to be almost silent in terms of production. The combined calipers (C1C2) reads in the range 2.92 - 5.94" for 3-1/2" OD, 2.992" ID tubing and ' various completion elements in logging interval. The combined calipers (C1C2) was used for the flowrate computation. ' Reported Surface Production at Standard Conditions: Gas Lift Gas = 700 Mscf/D Formation Gas = 650 Mscf/D 111 Water = 600 BWPD ' Measured Surface Production at Standard Conditions: Gas Lift Gas = N/A Formation Gas = 131.59 Mscf/D Water = 684.48 BWPD TBU M-11 Page 3 of 12 28/08/17 0 3 Table 1: Computed Production Rate at Standard Conditions Zones Water Oil Gas ft STB/D STB/D Mscf/D IInf. 1(3198.0-3205.0) 159.69 0.00 12.48 Inf.2(3214.0-3234.0) 502.57 0.00 118.51 IInf. 3(3549.0-3620.0) 22.22 0.00 0.64 Total (inc. Bottom) 684.48 0.00 131.59 I 4 Table 2: Computed Production Rate at Reservoir Conditions Zones Qt res. Production ft B/D ok IInf. 1 (3198.0-3205.0) 347.65 13.23 Inf.2 (3214.0-3234.0) 2250.62 85.68 1 Inf.3(3549.0-3620.0) 28.59 1.09 Contributions by phase IZones Qv/ res. Qo res. Qg res. ft B/D B/D B/D I W M 0 II G I Inf. 1 (3198.0-3205.0) 160.23 0.00 187.43 III Inf.2(3214.0-3234.0) 504.30 0.00 1746.32 Inf.3(3549.0-3620.0) 22.31 0.00 6.28 I I I I I I I I I TBU M-11 Page 4 of 12 28/08/17 • I •5. Interpretation Profile : Flowing Survey TBU M-11 1 Schlumberger Company: Hilcorp Alaska, LLC Test: PLT Field: McArthur River Field Date: 28-Aug-2017 Well: TBU M-11 Survey: Flowing IGR SCVL C1C2 Depth Z SPIN SPI1 WTEP WPRE WFDE Hodpups QZT QZI 0 GAPI1300 -140ft/min 140 2 in 7. (ft) -20 rps 25 -60 rps260 50 °F150 0 psid700 -0.2g/cc 1.2 0 H 1 0 B/D3000 0 B/[3000 :FO-1 Mangy — p 3 0 0 2160E 3 1 i = =1801 1 - 001:f X201 ID FO-1 Mangy 0 J = = JID 1 zucl 280CE I ill SFO-1 Masa_,—..= 1 0 npll"HP"Pa 11.,f-5,10- iria°1 � � e 20� <2 solati •-ackc� = Jiii , a 1 solati X600 -'acke •- - E 0 ii 8a Ill It C; solati=- ='ack _E. I 0 0oo _ , (is o I o solati,- -ack>E i 1 ) O C X1400 I' I 120Ct_ • X40c X6 ( I 0_ _ i, X000= 1 X201:E • '`,' htla j :Ck t 0 it o 1 TBU M-11 Page 5 of 12 28/08/2017 • S I 6. Basic Sensors and Match Data: Flowing Survey TBU M-11 I Schlumberger Company: Hilcorp Alaska, LLC Test: PLT Field: McArthur River Field Date: 28-Aug-2017 Well: TBU M-11 Survey: Flowing IGR SCVL C1C2 Depth Z SPIN SP11 WTEP WPRE WFDE Velocity match ater holdup mate 0 GAPI1300 -140ft/min 140 2 in 7. (ft) -20 rps 25 -60 rps 260 50 °F 150 0 psia1700 -0.2 g/cc 1.2 -20 ft/min 140 -0.2 1.2 VASPIN F1,11 YW_FLV F1,11 II 'ASPINZ-> F1,IW_FLV7 1,l 00 r4" FO 1 Mand_60(1= 6 GEE=11 D 6 1800 — — 120Ci 1 D ond, 401 ® O O ) 7r' FO-1 Ma _ _ O O 0 1 I lad 1 O ,, /2" -1 Mandl-00i rrnp V ae 11 Il 11 4-- I O X200 .; c 11 1/ _ - fsolat ackefE = J. —° 400 ❑o II o O T ❑ Isolaf-_ '-cker '_I ib ° O ,t, € 0 , 11 0 O ' a Isolat -cker- _ f t ° O 0 cool 0 1i1 0 o O ' a I t=0 fsolati- -cke = 4 } Q Tt� • 1 0 ❑ ' X1402 n ❑ II A0.2II ❑ II 0 = II ❑ a X00(1= ° o I20( ❑ I = _ .. ° i , ° II ❑ x600 II ❑ II 0 1800= II ❑ X000 ° II ❑ o i ® 3# 7 M�400 0 ® 9 N \i 0 Q 0 0 11 Q � ° I TBU M-11 Page 6 of 12 28/08/2017 • • 7. DEFT Water Holdup Data: Flowing Survey TBU M-11 Schlumberger Company: Hilcorp Alaska, LLC Test: PLT Field: McArthur River Field Date: 28-Aug-2017 Well: TBU M-11 Survey: Flowing IDFH1 DFH2 DFH3 DFH4 Depth Z DFB1 DFB2 DFB3 DFB4 Hodpups -0.2 1.2 -0.2 1.2 -0.2 1.2 -0.2 1.2 (ft) -50 Hz 550 -50 Hz 550 -50 Hz 550 -50 Hz 550 0 -I 1 b b = - 0 0 1 _1600= O O =1800 1 - I 1 _2000_ _ — 1 -2200=_ I I op 1 Ch1 ?1 C� =2400= 0 0 (h O C: E3` I =2600= =2800= e s ,l* --%0004- - _- _ * - » _ _,-3200E.-- =3200 ■. 111 SW 7 =-3400= E. _ O 3600- - o N ( 0 0 =3800= m o - _ I11 m 0 =4000- ck 0 o 11 CD (; =_4200= 0 -4400- I =4600= =-4800 E = _ I =5000= - _ I =5200= =5400= _ _ 5600 -E5800E 6000=_ = I =6200= ® ' ® =6400E n I I I TBU M-11 - ___ L m m Page 7 of 12 28/08/2017 I • • 8 Table of Abbreviations I Tool Mnemonic Channel Description Units: Description CVEL Cable velocity I CCLD/ B/D Barrels per Day CCLC Casing Collar Locator Discriminated/Calibrated DFB1/2/3/ scf/bbl Standard Cubic Feet per Barrel 4 DEFT bubble count per probe I DFH1/2/3/ cp Viscosity centipoises 4 DEFT water holdup per probe ft/m Feet per minute SCV1 Depth corrected cable speed to in-line spinner g/cc Grams per cubic centimeter SCVL Depth corrected cable speed to spinner I MMSCF/D Million Standard Cubic Feet per Day GHHM2 Field calculated combined gas holdup MSCF/D Thousand Standard Cubic Feet per Day DFHM Field calculated combined water holdup Res. To denote reservoir conditions(downhole) MW FD Field pressure derived density I rps Revolutions per second GR Gamma Ray GHB1/2/3/ S.C. To denote surface conditions(uphole) 4 GHOST gas bubble count per probe I GHH1/2/3/ SCF Standard Cubic Feet 4 GHOST gas holdup per probe STB/D Stock Tank Barrels per Day SPI1 In-line spinner WPRE Pressure I PVT: Bo Pressure Volume Temperature DPHZ Pressure derived density(from Emeraude) Oil volume factor PFC1/PFC2 PSP Caliper 1 and Caliper 2 Bw Water volume factor Q Rate I Relative bearing for probe 1 of second tool Bg Gas volume factor D1 RB2 (GHOST) FVF Fluid volume factor D1 RB Relative bearing of probe 1 GOR Gas Oil Ratio SPIN Spinner(fullbore or turbine) I Holduput Ratio of produced water to total fluids WTEP Temperature Fraction of fluid present in an interval of pipe TENS Tension Uncorrected Fluid Density(from I Interpretation: UWFD gradiomanometer) WFDE Well fluid density(from gradiomanometer) Correlation Model L-G:Liquid Gas W-H:Water Correl. Hydrocarbon;O-W Oil-Water I ID Internal Diameter PSP Production Services Platform Q Cumulate Rate with continuous solution DEFT Digital First Entry Tool(Water holdup) QZI Incremental rate per zone GHOST Gas Holdup Optical Sensor Tool(Gas holdup) I QZT Cumulative Rate track with zonal contribution Regime Modeled Spinner Calibration: Slope of rps/(ft/m). Defines conversion of YG Gas Holdup Slope spinner to velocity. I YO Oil Holdup Int Intercept of line of slope(defines velocity) Difference between up/down passes. This is the I YW Water Holdup Threshold velocity required to initiate rotation of the spinner. YW FLV Water Holdup from DEFT Z Zone: Yellow-spinner calibration I Red-Perforation White-Inflow Zones Gray:Calculation(stable)zone I I ITBU M-11 Page 8 of 12 28/08/17 • 9 Well and Job Data 9.1 Well Schematic I SCHEMATIC Steelhead Well M-11 As Completed: 12/07/2011 .11 IhLn o V,-1,111 I 1 Casing&Tubing Detail CONN MIN ID TOP 8TM BTM jou 28'Conductor SIZE Wt GRADE (MD) (ND;: ECP Stage Collar 28' _.,__„-. 2T Surface 470 470 r' 13-3/8" 68 E-.1. 12415 Surface 1432' 142C �S/8" 47 -7,' 9.681 Surface 6618' 6240 7- 26 .-Nl. U.s 6276 5399 10283' 8939 ATC'+.376'Csg in 17 1/2'Hole 31/2" 9.3 33.80 tC-1. 2993 Surface 3f302' 2827" Completion Equipment Information I min owe ' DI9 tvo 0 3-1/2"9.38 TC-II 565'. 081' 181' 1:t 2.613" X Profile 35'Sf6l Mandrel 1509' 1494' ..-- 2.867" t_ 335'Si0-1 Mandrel 2408' 2316' -_-- 2.867' Corm II Pkr,4 Iso Pkrs 3 Y,"Sf0-1 Mandrel 29:1:" 2750' . :1."., 2.667.. t jilt. - A-5C Sands ■ 3 X-Profile 2942' 2773' t: 2813 EllEll , 8-3.135 Sands Y':Canon"HP"Packer 3002' 2822' 3211 GP Sleeve 3043' 2858' 5880' 3.750" e;y... • &8 Sa^� 5'Blank Ppe 3061' 2871' 5.000' 4.276' C-1 Sands 6. imer �'. 8 Ga Were Wrapped Screen 3179' 2979' 6.692' 4.25 � I MSV Screen Sleeve 3231' 3026' 6.692' 3830' . Comp II Surr Packer 8 Ga Wire Wrapped Screen 3238 3033' 6.693' 4.256' Biolatbn Pecker 3254' 30478.310' 3.830" GP Sleeve 3260' 3053' 5.880' 3.75[7' Stage Collar 5"Blank Pipe 3277 3068' 5.000' 4.279' 8 Ga Wire Wrapped Screen 3531' 333316 6.69?' 42256' I prt �, 9 a9"Csg in 12 W Hole Sands MSV Screen Sleeve 3617 3385 --- 3.830' 6.9:0' 8 Ga Wire Wrapped Screen 3624' 3397 4.156' M4a1 Isolation Packer 3640' 3407 3.830" cern ,. TOC .IP B 573"%7'Liner Hanger wr GP Sleeve 3645' 341.1 _ -, 3750" 9.929'_ ,. ZXP Liner Top Packer 5"Blank Pipe 3663' 3429 1-..Ute.! 1.276" I �TVBc ,,{ ,..„_ E Sands 8 Ga Wire Wrapped Screen 3789' 3550' 4.592" 1-156 ,yl. E-7 Sands MSV Screen Sleeve 3857' 3516' 6.693" 3930' 8 Ga Wire Wrapped Screen 3964' 3722' 6.592" 4256' Tagged Fill 6274' Isolation Pecker 3{{0' 3639` 6.310' 3.830' =11 '0' "�7����� GP Sleeve 3586' 3615` 5.880 3.750 I r.3r 7 °'+% TGC Ct 9.288- S'Blank Pipe 33903' 3661' 5.000' 4.276" t Cerram Retainer 81 8.461' 8 Ga Wire Wrapped Screen 4004' 3762' 6.592' 0.256" MSV Screen Sleeve 4056' 3BOT 5.697` 3.630" 8 Ga Wire Wrapped Screen 4051 3814' 6.692" 4.256" 7'x 3 W S-3 Packer Isolation Parker 4072' 3829' 6.319" 3.830" GP Sleeve 4078' 3835' 5...880" 3.750" I _ 7'x 3 34 FB-1 Packer 5"Blank Pipe 4096' 3852` 5.000" 4.276" 8 W Wire Wrapped Screen 4118' 3874' 6.697' 4.256' MSV Screen Sleeve 4171' 3926' 6.692' 3.830" 8 Ga Wire Wrapped Screen 1177' 3932' 6.692" 4.256' Comp-Perm II Sump Packer 4164' 3939' 6.125" 6.000' i _ 7"291 LTC-Casing4388' 3913' 7.000' 6.184" TGC 8 Pos�Se4 Ni=6.881' 33/2"9.30 IC-9 Tubing +'19' 39 74' 3.500" 2.992" 3 1/2 9.38 10-11HalfMuleshoe150.2C 2.920" .+r Swell Packers g t 8.83•'.0,014'.0.481',0.750' Perforation Detail y t 009533 I Zone Top(MD) Wm(MD) Top(TVDI Nm 1rnDt 1 Statin t Comment TOC 8 Poli-Set 61=0.374" A-SC 3,198' 3,205' 2.99T 3,003' 14 Oper• Dal lArc)1 `• A-SC. 3,211" 3.234' 3A31' 3,029' 14 Open B-3 3,519' 3.620' 3331' 3,388' 14 ownTGC d PpS+-;gel a1=9,510' B•5 3,310' 3,818' 3,571 3,506' II Open I 8-5 3,852 3,856' 3,611 3,615' 14 Open. 9-8 4,037 4.054' 3,790 3.811" 14 Open C-1 1,135' 4.140' 3.891 3.896' 14 Open I C-1 4,143' 4.180' 3.899 1 040 _35' 14 Open 3-15 6,239 6,244' 5.923 5 326' S Open 10/18/15 0.16 6,304' 6.30"' 5,980 5,984' 6 Open 10/27/15 E3 6,970' 6,992' 6.521 6,539' 9 Open 12/14/14 E5 7,242' 7,787' 8,734 6,758" 9 Isolated 11/28/14 E5 7,447 7,491' 6,888 6,920' t Isolated 11/28/14 MAX HOLE ANGLE-43.9°@ 7,689'MC E-7 7,588' 7,595' 6,990 6,995' 4 Isolated 12/20/2012 I TO 1D,29D'MD/8.945IVO r-11 8,916' 8.977' 7,975 7.997 9 Isolated P1371)8,975',/7,9961-VD x-158 9,270 9,290 8,209' 8,223' t Isolated 1.16 9,120' 9,M0 8317' 8,331' 6 Isolated G-05 9,630' 9.868' 8.613' 8,641' 5 Isolated Updated by JLL 11/11'15 I TBU M-11 Page 9 of 12 28/08/17 I • 0 9.2 Spinner Calibration: Flowing Survey I I ■ • JI n III -:00 i' I Irps ersus.ft-lin Threshlint 0.5833 II Ca6b.Zone Slope (+) Slope(-) Int(+) Int(-) Int.Diff. Ift ft/min ft/min fUmn o 3154.5-3194.0 0.084 N/A -111.26 -124.16 12.90 O 3327.0-4138.9 0.105 0.112 2.92 -5.37 8.29 IA- 6423.6-6496.3 0.085 0.084 5.01 -7.89 12.90 I I I I I I ITBU M-11 Page 10 of 12 28/08/17 9.3 Tool String IProduction Log: Toolstring Equip name Length MP name Offset MH-22 37.44 I lir AH-38 35.87 ERS-E 35.58 ERS-E I mg ERS-E Idle SAH-G 34.00 r I IEQF-43[2] 32.68 I IEQF-43[1] 26.68 I I PSTP-B:28 20.68 { GR 16.98 I 18 /PSTC 16.68 PSC-A PrTC-A280 I StringPSTCToo B 0.00 S ottom PBMS-B:281 Tempera 13.93 I 3 ore CQG Pres 13.58 sure CCL 13.17 /DBMS 12.42 Inline Sp 6.04 I inner DGMK-B:85 12.42 4 Gradionia 10.91 PGMC43:854 nometer P`CH_Gradr - ' Accelero 10.91 I 0:4522 meter Aocelero:85 4 I ti____---DGMC 7.67 PILS-A:75 7.67 1 11 PILS-A:751 + Spinner 6.04 I J_f--PILS-A 5,14 PECS-A:10 5.14 7 PFOC-A:807 I EPROBE[3] Spinner 1.87 EDROBE[2] _ /Caaliper 1.87 SP>TRdER_2. �) !`�..Probes 1.48 �OBE[1] -,1 ,I PFCC-A 0.00 Relative 0.00 1.1 Bearing TOOL ZERO Lengths are in ft Maemum Outer Diameter=1.688 in I Lev:Sensor Location.Value:Gating Offset All measurements are relative to TOOL ZERO ITBU M-11 Page 11 of 12 28/08/17 I • 0 10 APPENDIX Z: Zone Color Code IAPPENDIX Z TRAC K C OLOUR C ODINC, 1 Depth Z II (IT ) 1 I I I I Spinner calibrations I zones are I shown in - NI_ rg yellow. , PP I -4709 1 Linear inflow zones shown I Perforations : in white. I are shown . me i 1 in red. 480 9 1 I Stable rate 4 i 1 zones — : d a shown in I -490. II grey. I ITBU M-11 Page 12 of 12 28/08/17 STATE OF ALASKA • AisKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown El Performed: Suspend❑ Perforate 2 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill❑ Perforate 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 0 Exploratory ❑ 210-145 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20590-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 • Trading Bay Unit/M-11 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): • N/A McArthur River Field/Middle Kenai G Gas Pool 11.Present Well Condition Summary: Total Depth measured 10,290 c feet Plugs measured 6,950 feet true vertical 8,945 . feet Junk measured 6,929 feet Effective Depth measured 6,929 feet Packer measured See Schematic feet true vertical 6,489 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,432' 13-3/8" 1,432' 1,420' 5,020 psi 2,260 psi Intermediate Production 6,618' 9-5/8" 6,618' 6,240' 6,870 psi 4,760 psi Liner 3,884' 7" 10,283' 8,940' 7,240 psi 5,410 psi Perforation depth Measured depth 3,198-9,868 feet _ ZUU �sED k�EB09 U True Vertical depth 2,997-8,641 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 3,002'(MD) 2,822'(TVD) Packers and SSSV(type,measured and true vertical depth) See Schematic 12.Stimulation or cement squeeze summary: 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: 0 619 48 120 45 Subsequent to operation: 0 630 46 196 40 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development[] . Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas E s WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-577 Contact Stan W.Golis Email sgolis(a�hilcoru.com Printed Name GStaan W.Golis Title Operations Manager Signature . ;0,c,.— (A_) / , Phone (907)777-8356 Date 11/13/2015 Form 10-404 Revised 5/2015 J� l Z /4-I5' DMS 1N It rV S 2015 (J /�6�� l/"" Submit Original Only Steelhead Well M-11 II 0 SCHEMATIC As Completed: 12/07/2011 nil.,,.,,tl,-ww:,.I I t Casing&Tubing Detail 28"Conductor SIZE WT GRADE CONN MIN ID TOP BTM BTM A14_ , (MD) (TVD) 470' ECP Stage Collar 28" Structural 27" Surface 470' 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' 7" _ 26 L-80 DWC 6.276 6399' 10283' 8939' II13 3/8"Csg in 17 1/2"Hole 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002' 2822' I Completion Equipment Information 1 Item Depth MD Depth TVD OD ID 3-1/2"9.38 TC-Il SCSSV 481' 481' 5.176" 2.813" X Profile 3 34"5F0-1 Mandrel 1509' 1494' 5.313" 2.867" Comp II Pkr,4 Iso Pkrs 3'''A"SFO-1 Mandrel 2408' 2316' 5.313" 2.867" 3'A"SF0-1 Mandrel 2920' 2750' 5.313" 2.867" A-5C Sands 3 34"X-Profile 2946' 2773' 3.960" 2.813" '' B-3,B-5 Sands Comp II"HP"Packer 3002' 2822' 8.320" 6.000" GP Sleeve 3043' 2858' 5.880" 3.750" B-8 Sands 5"Blank Pipe 3061' 2874' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3179' 2979' 6.692" 4.256" '''.1-"" I ....,, C-1 Sands MSV Screen Sleeve 3231' 3026' 6.692" 3.830' Comp II Sump Packer 8 Ga Wire Wrapped Screen 3238' 3033' 6.692" 4.256" Isolation Packer 3254' 3047' 8.310" 3.830" MI GP Sleeve 3260' 3053' 5.880" 3.750" Stage Collar 5"Blank Pipe 3277' 3068' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3534' 3306' 6.692" 4.256' Bridge N 9 5/8"Csg in 12'h"Hole MSV Screen Sleeve 3617' 3385' 6.692" 3.830' Plug LD 6,950' -- D Sands 8 Ga Wire Wrapped Screen 3624' 3392' 6.692" 4.256' with 20' Isolation Packer 3640' 3407' 8.310" 3.830" cemeOC n # 9 5/8"x 7"Liner Hanger w/ GP Sleeve 3645' 3412' 5.880" 3.750" 6,929' , ZXP Liner Top Packer 5"Blank Pipe 3663' 3429' 5.000" 4.276" TTVBP E Sands 8 Ga Wire Wrapped Screen 3789' 3550' 6.692" 4.256' @ I E-7 Sands MSV Screen Sleeve 3857' 3616' 6.692" 3.830' 7,210' 8 Ga Wire Wrapped Screen 3964' 3722' 6.692" 4.256' BINMEIGNIZ Tagged Fill @ 8,274' Isolation Packer 3880' 3639' 8.310" 3.830" Fish:10' GP Sleeve 3886' 3645' 5.880" 3.750" Titan 2-1g" 'ir `'I ' TOC@ 8,286' Strip Gun v. 5"Blank Pipe 3903' 3661' 5.000" 4.276" Cement Retainer @ 8,491' 8 Ga Wire Wrapped Screen 4004' 3762' 6.692" 4.256" MSV Screen Sleeve 4050' 3807' 6.692" 3.830" W " 8 Ga Wire Wrapped Screen 4057' 3814 6.692" 4.256" 7"x 3'/"S-3 Packer Isolation Packer 4072' 3829' 85:83810'°"' .310 3.830" GP Sleeve 4078' 3835' 5.880 3.750" 7"x 3'/z"FB-1 Packer 5"Blank Pipe 4096' 3852' 5.000" 4.276" y - 8 Ga Wire Wrapped Screen 4118' 3874' 6.692" 4.256" Pt MSV Screen Sleeve 4171' 3926' 6.692" 3.830" ®tE 8 Ga Wire Wrapped Screen 4177' 3932' 6.692" 4.256" ` Comp-Perm II Sump Packer 4184' 3939' 8.125" 6.000" l'`',Ni'' 7"29#LTC-Casing 4188' 3943' 7.000" 6.184" TOC&Posi-Set#1=8,991' 3-1/2"9.38 TC-Il Tubing 4219' 3974' 3.500" 2.992" 3 1/2 9.38 TC-II Half Muleshoe 6351' 6020' 3.500" 2.920" 2 I I Swell Packers @ 8,831',9,014',9,491',9,759' Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(ND) Density Status Date,Comment '' ' TOC&Posi-Set#1=9,374' (SPF) IA-SC 3,198' 3,205' 2,997' 3,003' 14 Open A-5C 3,214' 3,234' 3,011' 3,029' 14 Open B-3 3,549' 3,620' 3,321' 3,388' 14 Open a z e B-5 3,810' 3,848' 3,571' 3,608' 14 Open TOC&Posi-Set#1 =9,510' B-5 3,852' 3,856' 3,611' 3,615' 14 Open :ASLiel B-8 4,032' 4,054' 3,790' 3,811' 14 Open C-1 4,135' 4,140' 3,891' 3,896' 14 Open C-1 4,143' 4,180' 3,899' 3,935' 14 Open 0-15 6,239 6,244' 5,923' 5,928' 6 Open 10/28/15 0-16 6,304' 6,309' 5,980' 5,984' 6 Open 10/27/15 7"Liner in 8%"Hole E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 MAX HOLE ANGLE=43.9°@ 7,689'MD E-7 7,588' 7,595' 6,990' 6,995' 4 Isolated 12/20/2012 TD 10,290'MD/8,945'TVD F-11 8,946' 8,977' 7,975' 7,997' 6 Isolated PBTD 8,97577,996'TVD F-15B 9,270' 9,290' 8,209' 8,223' 6 Isolated F-16 9,420' 9,440' 8,317' 8,331' 6 Isolated G-05 9,830' 9,868' 8,613' 8,641' 5 Isolated Updated by:JLL 11/13/15 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-11 E-Line 50-733-20590-00 210-145 10/24/15 10/28/15 Daily Operations: 10/24/2015 -Saturday PJSM. Rig up on M-11. Move hatch cover. Install W/L bridge. R/U w/I w/2.5" dummy guns& 2.70 GR. P/T lub t/ 2500 psi,good. RIH tag @ 7,086' (wlm), POOH. R/D w/I. R/U a-line. M/u GR/CCL, 7" Ace double umbrella plug. P/T lubricator t/2500 psi,good. RIH, correlate into position, setplug @ 6,950'. POOH. C/o BHA. P/u 40' 2" dump bailer, load w/3 gal 6/12 ceramic shot. RIH t/6,920' dump shot. POOH, disk blown, shot dumped. Mix& load 5 gal premium Class "H" cmt as per plug procedure. RIH t/6,920' dump cmt. POOH, disk blown, cmt dumped. Secure well. Install night cap. L/d lubricator. WOC. Rest crew's. 10/25/2015-Sunday PJSM. R/U a-line tools w/2.5" LIB. P/T lubricator t/2500 psi, good. RIH tag top of plug. Set down to close vent valve @ 6,943'. POOH, good markings on LIB. C/O tools. P/U 40' of 2" dump bailer, loaded with 5 gal,ACE. Mix cmt. RIH t/6,920', dump cmt. POOH, disk blown, cmt dumped. Re-disk&charge bailer. Refill w/cmt. RIH t/6,920', dump cmt, POOH. 10/26/2015- Monday OOH w/dump bailer, disk blown, cmt dumped. Re-wire teardrop. Re-disk&charge bailer. Refill w/cmt. RIH t/ 6,910', dump cmt. POOH, w/disk blown, cmt dumped. Re-wire teardrop. Re-disk& charge bailer. Refill w/cmt. RIH t/6,910', dump cmt. POOH, w/disk blown, cmt dumped. Rig down. Secure well. Install night cap. Rest Crew. WOC. 10/27/2015 -Tuesday PJSM. Wait on change out chopper. R/u a-line, GR/CCL, 2.5" LIB, P/T t/2500,good. Rih t/tag TOC @ 6,929'. POOH. Wait on chopper f/crane op. R/u w/gr/ccl,Titan 2 1/2", 15 grain RDX, 0 phasing, 6 spf strip gun. Rih correlate to PETRA 11/7/2014 tie in log, verify w/geologist, placing top shot @ 6,304' btm at 6,309',fired shots. Had good indication at surface shots fired. Monitored pressure w/no change, temporarily restricted from upward movement, dropped below next collar and POOH free. R/D all shots fired. Secure well, turn over to production. 10/28/2015-Wednesday Discuss options w/town. Decide t/shoot D-15 sands. PJSM. Wait t/arm guns until after morning chopper. R/u w/gr/ccl,Titan 2 1/2", 15 grain RDX, 0 phasing, 6 spf strip gun. Rih correlate to PETRA 11/7/2014 tie in log,verify w/geologist, placing top shot @ 6,239' btm at 6,244', fired shots. Had good indication at surface shots fired. Monitored pressure w/no change. Try to p/u, unable to move up hole. Able to move down, wk do hole keep attempting to move up, no go. Lost down & up movement @ 6,334'. Cont. wk tools no movement. Flow well & keep working tools. Cont. working with no luck. Pull out of rope socket @ 3050 lbs tension. POOH. R/d E-line. R/u Wait for fishingtools from beach. M U 1 3 8 JDC, rih find & latch fish 6 830' wlm, wk fish, pull free. POOH w/I. at / / @ t/6,228' pulledtight, work free. POOH, recover fish w/o last 10' of strip, w/2.125" cent. strip gun BTM. L/d fish. M/U 2.34 r. Rih t/6 410' clear. POOH. R d w/I. Secure well.Turn over t/ production. g / • arENIMMIIIIMMIMMMINSINOMMINIMIMMANIMIMMIENIMROMIEMIMMEMESEIMSMIOMIEM OF Tit �w���\I%%i THE STATE Alaska Oil and Gas � q of F �►;.�.��� A LAsKA Conservation Commission 4 tt4333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ted Kramer scoNE Sr. Operations Engineer � Di ._-. Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Gas Pool, TBU M-11 Sundry Number: 315-577 Dear Mr. Kramer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A , Cathy P. Foerster Chair DATED this day of October, 2015 Encl. RBDMS pit 13 2015 RECEIVED STATE OF ALASKA SEP 2 1 '015 � ALASKA OIL AND GAS CONSERVATION COMMISSION S 10 t 9 ( )g APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate 0 Other Stimulate El Alter Casing El Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0/ 210-145 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20590-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A 4 Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit/M-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730, McArthur River Field/Middle Kenai G Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): ' 10,290 - 8,945 '7,210 ' 6,710 7,210 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,432' 13-3/8" 1,432' 1,420' 5,020 psi 2,260 psi Intermediate Production 6,618' 9-5/8" 6,618' 6,240' 6,870 psi 4,760 psi Liner 3,884' 7" 10,283' 8,940' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,198'-9,868' ' 2,997'-8,641' 3-1/2" 9.2#/L-80 3,002 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): See Schematic See Schematic/ 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ welopment 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/5/2015 Commencing Operations: OIL L 1I WINJ ❑ WDSP❑ Suspended El16.Verbal Approval: Date: GAS LrJ° WAG ❑ GSTOLI SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature �j/e Phone (907)777-8420 Date 9/21/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I _ 5 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance CI Other: Spacing Exception Required? Yes ❑ No E( Subsequent Form Required: /0—y0y 4,,,,,„Li,,_ AO �,Approved by: COMMISSIONER THEPPRCOVEDMMISSIONBY Date: /Q..9... �S ORI I N A L..... eNI, 9120)ks- ��z,.s-- A770- , diRBDMSS,OCT 13 2015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Well Work Plan Well: M-11 llilcorp Alaska,LL Date:9/21/15 Well Name: M-11 API Number: 50-733-20590-00 Current Status: Gas Producer Leg: Leg Al, SW Corner Estimated Start Date: October 5, 2015 Rig: NA Reg.Approval Req'd: Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill 210-145 Number: First Call Engineer: Ted Kramer (907) 777-8420 (0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907)398-9904(M) Current Bottom Hole Pressure: 1796 psi @ 7,500' MD,6,926' TVD (From 12/1014 Prod Log) Maximum Expected BHP: 2,617 psi @ 6,309 MD, 5,985'ND (Calc'd assuming naturally pressured Reservoir) Max.Anticipated Surface Pressure: 2019 psi (Using 0.1 psi/ft to surface) Well Summary M-11 is currently producing 625 mcfd at 58 psi flowing tbg pressure. Gas production was observed with a downhole camera as coming from perforations up hole through one of the sliding sleeves with only water coming from the E-3 perforations. This work involves Setting a plug above the E-3 perforations and placing 20'of cement on top of the plug for isolation.' Perforations will then be shot in the D-15 and 16 benches to test for commercial quantities of gas. The D-16 bench will be flow tested independently of the D-15. If the D-16 flows water, an additional plug will be set above the D-16 before perforating the D-15 interval. Procedure: 1. MIRU a-line unit. Pressure test lubricator to 2,000 psi. 2. RIH with 2-1/8"GR to 6,980'. POOH with GR. 3. PU, RIH with Isolation plug to 6,950' (+/-)and set. POOH. 4. PU dump bailer. Mix and load cement and RIH placing cement on top of plug. Repeat until 20' of cement has been placed on top of the plug (+/-6930 TOC). SD WOC. -` 5. PU 2"dummy perf gun and RIH and tag TOC. POOH. 6. PU live 2"perf gun , RIH and log on depth with correlation log placing guns on depth to perforate the D-16 perforations from 6,309—6,304'. PU and Monitor pressure increase. POOH. 7. Put well to production and flow test. Note: If the D-16 perforations flow a lot of water,a plug will be set above the D-16 prior to perforating the D-15. 8. Report results to Operations Engineer. 9. If successful, go to step 11. Otherwise continue to Step 10. 10. PU live 2"perf gun , RIH and log on depth with correlation log placing guns on depth to perforate the D-15 perforations from 6,244—6,239'. PU and Monitor pressure increase. POOH. 11. Turn well over to production. RDMO E-line unit. Attachments: 1. As-built Schematic 2. Proposed Schematic II Steel ead -11 0 SCHEMATIC •• As Cohmp etedll M-07/2011 As Perfed: 12/14/14 ILL,., tf.,.l.,.i ii Casing&Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM 28"Conductor (MD) (TVD) ECP Stage Collar 28" Structural 27" Surface 470' 470' — 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' ' it 7" 26 L-80 DWC 6.276 6399' 10283' 8939' 1 3/8"Csg in 17 1/2"Hole 3 1/2" 9.2 L-80 TC-Il 2.992 Surface 3002' 2822' d Completion Equipment Information Item Depth MD Depth TVD OD ID d 3-1/2"9.3#TC-II SCSSV 481' 481' 5.176" 2.813" X Profile 3'/:"SF0-1 Mandrel 1509' 1494' 5.313" 2.867" Comp II Pkr,4 Iso Pkrs 3 W'SF0-1 Mandrel 2408' 2316' 5.313" 2.867" 3'''A"SF0-1 Mandrel 2920' 2750' 5.313" 2.867" — A-5C Sands 3'A"X-Profile 2946' 2773' 3.960" 2.813" B-3,B-5 Sands Comp II"HP"Packer 3002' 2822' 8.320" 6.000" GP Sleeve 3043' 2858' 5.880" 3.750" L- B-8 Sands 5"Blank Pipe 3061' 2874' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3179' 2979' 6.692" 4.256" C-1 Sands MSV Screen Sleeve 3231' 3026' 6.692" 3.830' Comp II Sump Packer 8 Ga Wire Wrapped Screen 3238' 3033' 6.692" 4.256" Isolation Packer 3254' 3047' 8.310" 3.830" GP Sleeve 3260' 3053' 5.880" 3.750" ® Stage Collar 5"Blank Pipe• 3277' 3068' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3534' 3306' 6.692" 4.256' NIR 9 5/8"Csg in 12'A"Hole MSV Screen Sleeve 3617' 3385' 6.692" 3.830' 8 Ga Wire Wrapped Screen 3624' 3392' 6.692" 4.256' Isolation Packer 3640' 3407' 8.310" 3.830" 9 5/8"x 7"Liner Hanger w/ GP Sleeve 3645' 3412' 5.880" 3.750" –4. ZXP Liner Top Packer 5"Blank Pipe 3663' 3429' 5.000" 4.276" TTVBP E Sands 8Ga Wire Wrapped Screen 3789' 3550' 6.692" 4.256' @ E-7 Sands MSV Screen Sleeve 3857' 3616' 6.692" 3.830' 7,210' 8 Ga Wire Wrapped Screen 3964' 3722' 6.692" 4.256' Tagged Fill @ 8,274' Isolation Packer 3880' 3639' 8.310" 3.830" GP Sleeve 3886' 3645' 5.880" 3.750" TOC @ 8,286' 5"Blank Pipe 3903' 3661' 5.000" 4.276" Cement Retainer @ 8,491' 8 Ga Wire Wrapped Screen 4004' 3762' 6.692" 4.256" MSV Screen Sleeve 4050' 3807' 6.692" 3.830" 8 Ga Wire Wrapped Screen 4057' 3814' 6.692" 4.256" 7"x 3'/"S-3 Packer Isolation Packer 4072' 3829' 8.310" 3.830" UGP Sleeve 4078' 3835' 5.880" 3.750" 7"x 3'/i'FB-1 Packer 5"Blank Pipe 4096' 3852' 5.000" 4.276" — 8Ga Wire Wrapped Screen 4118' 3874' 6.692" 4.256" MSV Screen Sleeve 4171' 3926' 6.692" 3.830" 8Ga Wire Wrapped Screen 4177' 3932' 6.692" 4.256" Comp-Perm II Sump Packer 4184' 3939' 8.125" 6.000" • 7"29#LTC-Casing 4188' 3943' 7.000" 6.184" 3-1/2"9.3#TC-Il Tubing 4219' 3974' 3.500" 2.992" TOC&Posi-Set#1 =8,991' 3 1/2 9.3#TC-II Half Muleshoe 6351' 6020' 3.500" 2.920" 11 n Swell Packers @ 8,831',9,014',9,491',9,759' Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Density Status Date,Comment TOC&Posi-Set#1=9,374' (SPF) A-5C 3,198' 3,205' 2,997' 3,003' 14 Open WalC) !_;;::. A-SC 3,214' 3,234' 3,011' 3,029' 14 Open B-3 3,549' 3,620' 3,321' 3,388' 14 Open B-5 3,810' 3,848' 3,571' 3,608' 14 Open TOC&Posi-Set#1 =9,510' B-5 3,852' 3,856' 3,611' 3,615' 14 Open IM 111 ti B-8 4,032' 4,054' 3,790' 3,811' 14 Open C-1 4,135' 4,140' 3,891' 3,896' 14 Open C-1 4,143' 4,180' 3,899' 3,935' 14 Open E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 ES 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 7"Liner in 8''"Hole E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588' 7,595' 6,990' 6,995' 4 Isolated 12/20/2012 F-11 8,946' 8,977' 7,975' 7,997' 6 Isolated MAX HOLE ANGLE=43.9°@ 7,689'MD F-15B 9,270' 9,290' 8,209' 8,223' 6 Isolated TD 10,290'MD/8,945'TVD F-16 9,420' 9,440' 8,317' 8,331' 6 Isolated PBTD 8,975'/7,996'TVD G-05 9,830' 9,868' 8,613' 8,641' 5 Isolated Updated by:JLL 01/13/15 Steelhead Well M-11 eIII S PROPOSED • As Completed: 12/07/2011 As Perfed: 12/14/14 this„,„v„-L.,I L Casing&Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM /4_ JJ 28"Conductor (MD) (TVD) ECP Stage Collar 28" Structural 27" Surface 470' 470' — 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' I 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' 0 7" 26 1-80 DWC 6.276 6399' 10283' 8939' '13 3/8"Csg in 17 1/2"Hole 3 1/2" 9.2 L-80 TC-Il 2.992 Surface 3002' 2822' Completion Equipment Information Item Depth MDDepth TVD OD ID 3-1/2"9.36 TC-II SCSSV 481' 481' 5.176" 2.813" X Profile 3 34"SF0-1 Mandrel 1509' 1494' 5.313" 2.867" Comp II Pkr,4 Iso Pkrs 3'%"SF0-1 Mandrel 2408' 2316' 5.313" 2.867" 3'/=="510-1 Mandrel 2920' 2750' 5.313" 2.867" ' • A-5C Sands 3%"X-Profile 2946' 2773' 3.960" 2.813" 6-3,6-5 Sands Comp II"HP"Packer 3002' 2822' 8.320" 6.000" GP Sleeve 3043' 2858' 5.880" 3.750" — B-8 Sands 5"Blank Pipe 3061' 2874' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3179' 2979' 6.692" 4.256" C-1 Sands MSV Screen Sleeve 3231' 3026' 6.692" 3.830' Comp II Sump Packer 8 Ga Wire Wrapped Screen 3238' 3033' 6.692" 4.256" Isolation Packer 3254' 3047' 8.310" 3.830" GP Sleeve 3260' 3053' 5.880" 3.750" Id Stage Collar 5"Blank Pipe 3277' 3068' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3534' 3306' 6.692" 4.256' 9 5/8"Csg in 12'/,"Hole MSV Screen Sleeve 3617' 3385' 6.692" 3.830' Bridge D Sands 8 Ga Wire Wrapped Screen 3624' 3392' 6.692" 4.256' Plug @ "— Isolation Packer 3640' 3407' 8.310" 3.830" 6,950' 9 5/8"x 7"Liner Hanger w/ GP Sleeve 3645' 3412' 5.880" 3.750" with 2 cem no ZXP Liner Top Packer 5"Blank Pipe 3663' 3429' 5.000" 4.276" TTVBP 0 E Sands 8 Ga Wire Wrapped Screen 3789' 3550' 6.692" 4.256' @ ' E-7 Sands MSV Screen Sleeve 3857' 3616' 6.692" 3.830' 7,210' 8 Ga Wire Wrapped Screen 3964' 3722' 6.692" 4.256' Tagged Fill @ 8,274' Isolation Packer 3880' 3639' 8.310" 3.830" GP Sleeve 3886' 3645' 5.880" 3.750" TOC @ 8,286' 5"Blank Pipe 3903' 3661' 5,000" 4.276" Cement Retainer @ 8,491' 8 Ga Wire Wrapped Screen 4004' 3762' 6.692" 4.256" MSV Screen Sleeve 4050' 3807' 6.692" 3.830" 8 Ga Wire Wrapped Screen 4057' 3814' 6.692" 4.256" 7"x 3'/:'S-3 Packer Isolation Packer 4072' 3829' 8.310" 3.830" II GP Sleeve 4078' 3835' 5.880" 3.750" 5"Blank Pipe 4096' 3852' 5.000" 4.276" 7"x 3'A FB-1 Packer 8 Ga Wire Wrapped Screen 4118' 3874' 6.692" 4.256" MSV Screen Sleeve 4171' 3926' 6.692" 3.830" �• . 8 Ga Wire Wrapped Screen 4177' 3932' 6.692" 4.256" Comp-Perm II Sump Packer 4184' 3939' 8.125" 6.000" 7"296 LTC-Casing 4188' 3943' 7.000" 6.184" TOC&Posi-Set#1 =8,991' 3-1/2"9.36 TC-Il Tubing 4219' 3974' 3.500" 2.992" 3 1/2 9.36 TC-Il Half Muleshoe 6351' 6020' 3.500" 2.920" Swell Packers @ _ 8,831',9,014',9,491',9,759' Perforation Detail Density Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) (SPF) Status Date,Comment TOC&Posi-Set#1=9,374' A-5C 3,198' 3,205' 2,997' 3,003' 14 Open II ' A-5C 3,214' 3,234' 3,011' 3,029' 14 Open 8-3 3,549' 3,620' 3,321' 3,388' 14 Open B-5 3,810' 3,848' 3,571' 3,608' 14 Open *vvvs TOC&Posi-Set#1=9,510' 8-5 3,852' 3,856' 3,611' 3,615' 14 Open B-8 4,032' 4,054' 3,790' 3,811' 14 Open _ C-1 4,135' 4,140' 3,891' 3,896' 14 Open C-1 4,143' 4,180' 3,899' 3,935' 14 Open D-15 ±6,239 ±6,244' ±5,923' ±5,928' Future D-16 ±6,304' ±6,309' ±5,980' 5,984' Future 7"Liner in 8" "Hole E3 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 E5 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 E5 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 MAX HOLE ANGLE=43.9°@ 7,689'MD E-7 7,588' 7,595' 6,990' 6,995' 4 Isolated 12/20/2012 TD 10,290'MD/8,945'TVD F-11 8,946' 8,977' 7,975' 7,997' 6 Isolated PBTD 8,975'/7,996'TVD F-15B 9,270' 9,290' 8,209' 8,223' 6 Isolated F-16 9,420' 9,440' 8,317' 8,331' 6 Isolated G-05 9,830' 9,868' 8,613' 8,641' 5 Isolated Updated by:JLL 01/13/15 STATE OF ALASKA ALA, ,1 OIL AND GAS CONSERVATION COMM,__,ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations El Perforate 1 Other❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 111 Exploratory❑ 210-145 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20590-00 RECEIVED 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 18730 Steelhead Platform Trading Bay Unit M-11 JAN 1 4 2015 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G Gas Pool I 11.Present Well Condition Summary: A GCC Total Depth measured 10,290 feet Plugs measured 7,210 feet true vertical 8,945 feet Junk measured N/A feet Effective Depth measured 8,975 feet Packer measured See Schematic feet true vertical 7,996 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,432' 13-3/8" 1,432' 1,420' 5,020 psi 2,260 psi Intermediate Production 6,618' 9-5/8" 6,618' 6,240' 6,870 psi 4,760 psi Liner 3,884' 7" 10,283' 8,940' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet ;, 7 .1'1.`,, True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 3,002' 2,822' Packers and SSSV(type,measured and true vertical depth) Packers(See Schematic) TC-II SCSSV 481'(MD)/481'(ND) 12.Stimulation or cement squeeze summary: 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: 0 750 0 100 71 Subsequent to operation: 0 935 34 108 28 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development[] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil LI Gas Et WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUGD 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314-614 Contact Dan Taylor Email dtaylor@hilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature Phone 907 777-8319 Date 1/14/2015 n r— 2 t _ /r RBDMS 4 JAN 1 6 2015 Form 10-404 Revised 10/2012 Submit Original Only Hilcorp Alaska, LLC FHfkurpAla.ka.IAA: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-11 50-733-20590-00 210-145 11/24/14 12/15/14 Daily Operations: 11/24/14-Monday ARRIVE ON STEELHEAD PLATFORM @ 0800 HRS. ORIENTATION. INSTALL WIRELINE BRIDGE HAND RAILS. R/U LUBRICATOR &TOOLS. P/U LUBRICATOR&TEST TO 2000 PSI. OPEN SWAB VALVE&WIRELINE TOOLS SHOT UP LUBRICATOR. POSSIBLE ICE BRIDGE. CHECK TOOLS. REHEAD ROPE SOCKET SAME. TEST LUBRICATOR TO 2000 PSI. RIH WITH 2.75"GR TO 8,219'SLM (TAG SAME). POOH & L/D GR. FLUID LEVEL @ 4,220'. P/U & RIH WITH 2.50"X 10' BAILER& 10'OF 2.125" STEM SIMULATING LOGGING RUN TO EOT @ 6,351'. POOH SAME & L/D TOOLS.WAITING ON LOGGING TOOLS. LOGGING TOOLS TO ARRIVE ON STEELHEAD ON 11-26-14. 11/26/14-Wednesday LOAD OUT LOGGING TOOLS ONTO M/V RESOLUTION & FLY PERSONNEL TO STEELHEAD PLATFORM. BRIEF&ORIENTATE PERSONNEL. M/V RESOLUTION ARRIVED TO STEELHEAD @ 1100 HRS, OFFLOAD SAME. REMOVE WELL BAY HATCH. INSTALL WIRE LINE BRIDGE. R/U E-LINE LUBRICATOR&SHEAVES. P/U RDT-I LOGGING ASSEMBLY.ATTEMPT TO SURFACE TEST TOOLS. HAVING COMPATABILITY ISSUES WITH UNIT&TOOLS. DIAGNOSE ISSUES WITH ENGINEERING. FLY OUT REPLACEMENT CHIP PANEL& ENGINEER.CHANGE OUT PANEL&TEST TOOLS. TEST LUBRICATOR TO 250 LOW&2500 HIGH. RIH SLOWLY WITH RDT-I LOGGING ASSEMBLY. CURRENTLY AT 1,500'. 11/27/14-Thursday RIH SLOWLY WITH 2-1/8" RDT-I LOGGING TOOLS.TEST TOOLS AT 1,000' (TESTED GOOD).CONTINUE RIH, LOG FROM 5,753'TO 7,614'AT 10 FT/MIN WITH GENERATOR OFF. ESTABLISH PARAMETERS& LOG FROM 7,614' UP TO 6,757'AT 3 FT/MIN WITH GENERATOR ON. UNABLE TO OBTAIN CLEAR DATA DUE TO TOOL JUMPING DOWN HOLE. CALL ENGINEERING & DECISION WAS MADE TO MAKE 2 PASSES AT 8 FT/MIN. LOG FROM 7,614'TO 5,753'AT 5 FT/MIN, GENERATOR ON. LOWER TOOL STRING AND BEGIN SECOND PASS FROM 7,614'. CURRENTLY AT 6,020'AT 0600 HRS. 11/28/14-Friday CONTINUE LOGGING FROM 6,020' TO 5,715'WITH RDT-I LOG. POOH & L/D TOOLS. UPLOAD DATA SAME. LID SHEAVES& LUBRICATOR. P/U LUBRICATOR&SHEAVES. P/U 20' OF 2.5" 6 SPF 60 PHASE PERF GUNS& RIH. LOG ON DEPTH & PERFORATE FROM 7,4711-7,491'. POOH SAME. NO PRESSURE INCREASE AT SURFACE. L/D SPENT GUNS(ALL SHOTS FIRED). P/U 20'OF 2.5"6 SPF PERF GUNS. RIH, LOG ON DEPTH & PERFORATE FROM 7,451'-7,471', POOH SAME. 10PSI PRESSURE INCREASE AT SURFACE. L/D SPENT GUNS (ALL SHOTS FIRED). P/U 5'OF 2.5" 6 SPF PERF GUNS. RIH & LOG ON DEPTH, PERFORATE FROM 7,447'-7,451', POOH SAME. NO PRESSURE INCREASE AT SURFACE (SURFACE PRESSURE= 199 PSI). L/D SPENT GUNS(ALL SHOTS FIRED). P/U 5' OF 2.5" 6 SPF PERF GUNS. RIH & LOG ON DEPTH, PERFORATE FROM 7,282'-7,287'. POOH SAME. NO PRESSURE INCREASE AT SURFACE. L/D SPENT GUNS(ALL SHOTS FIRED). P/U 20' OF 2.5" 6 SPF PERF GUNS. RIH & LOG ON DEPTH, PERFORATE FROM 7,262'-7,282'. POOH SAME. (PRESSURE AT SURFACE=200 PSI). L/D SPENT GUNS. P/U 20'OF 2.5" 6 SPF PERF GUNS. RIH & LOG ON DEPTH.CURRENTLY PERFORATING FROM 7,242'- 7,262'. 11/29/14-Saturday FINISH POOH & L/D SPENT GUNS,ALL SHOTS FIRED.SURFACE PRESSURE @ 202 PSI. R/D E-LINE & LUBRICATOR. REMOVE WIRE LINE BRIDGE& INSTALL WELL BAY HATCH. LOAD OUT PERSONNEL ONTO M/V RESOLUTION DUE TO LOW VISIBILITY. ALL PERSONNEL RELEASED. TURN OVER WELL TO PRODUCTION. FINAL REPORT. Hilcorp Alaska, LLC IlikorpAhaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-11 50-733-20590-00 210-145 11/24/14 12/15/14 Daily Operations: 12/09/14-Tuesday WSM & Halliburton E-Line crew on location,standing by for arrival of wireline equipment. Unloaded/spotted Halliburton logging and perforating equipment+ Pollard tool basket. Unloaded MV Champion w/North crane and positioned equip w/South crane. Held PJSM w/production & Halb crew. R/U full lubricator w/grease- M/U 1.44" rope socket,3- 1.69" Tungsten Wt bars, 1.69"CCL/GR, 1.69" Pressure Sensor, 1.69"Temp Tool w/bullnose. M/U lubricator to wellhead and tested same to 500psi low/2,500psi high. Bled down pressure to 70#s-opened well flowing at 631bs (making 941,000 mmcfgd ^'24 bwpd). RIH to 2,946'&logged down to 7,500' @ 90 fpm-recorded 15 min stationary @ 7,500'-PUH to 7,400' & recorded 15 min stationary- PUH to 7,200' &recorded 15 min stationary- RBI to 7,500'&logged up to 2,946' @ 90 fpm (all recordings w/well flowing-shutin well for 1 hr and began recording down log from 2,946'. 12/10/14-Wednesday Recorded down log from 2,946'to 7,500' @ 90 fpm w/well shut-in. Recorded 15 min stationary @ 7,500'shut-in recorded 15 min stationary @ 7,400' shutin- recorded 15 min stationary @ 7,200'shut-in RBI to 7,500'and pulled log to 2,946' @ 90 fpm shutin. Pulled logging tools into lubricator and closed crown valve. N/D lubricator adapter because crown valve leaks- laydown lubricator. Held PJSM w/production and Halb crew-installed adapter for E-Line lubricator and mounted tool trap/BOP assm. Job halted to discuss influences of water column in well prior to perforating.Standing by for directions (conference call 08:00 hrs). 12/11/14-Thursday Standing by until Engineering determines plan forward.After roundtable discussions w/Engineering& Prod Supervisor the decision was made to wait on perforating E3& El. Rigged down Halliburton E-Line equipment. Pollard wireline crew on location at 20:00 hrs. 12/12/14-Friday PJSM w/production & Pollard E-Line crew. N/U adapter on tree- M/U full lubricator w/grease- M/U 40' of 2-1/2"cmt Q bailer w/CCL(Run#1)and pulled inside lub-m/u to tree and test to 250psi low/ 2,500psi high. Bled down pressure. 3 V J Opened well w/190 PSI (static)and RIH to 3,055'-set down (possibly in GP sleeve), clean pickup up, no drag-could not „<* get deeper- POOH. Changed profile on end of bailer to a taper(Run#2)- Pulled inside lubricator and tested-RIH to 8,190' and tagged btm- POOH. B/D tool string. M/U Run#3 (1- 1.70"wt. bar, 1.70" GR/CCL, Release Sub,2-1/2" Neo Products TTVBP). Pulled inside lubricator and tested. Opened well and TIN-logged into positiion-set btm of plug at 7,225'top at 7,210'. POOH. B/D tool string. M/U Run#4(1.70" CCL w/40' 2 1/2" cmt bailer). Armed and filled bailer with 3.2 gals of 11 v 1� ceramic beads. Pulled inside lubricator&tested. Opened well and RIH-tied in w/CCL-stopped at 7,208' and dumped '11/ beads. POOH. Re-armed and filled bailer with 8.2 gals of 17#Neo Products cmt slurry(mixed as per package instructions)(Run#5-same tool string as previous run)-pulled inside lubricator and tested. Opened well and RIH-tied in w/CCL-stopped at 7,208'and dumped cmt. POOH. Rearmed and filled bailer with 5.0 gals of same 17#cmt slurry(Run #6-same tool string as previous run)-pulled inside lubricator and tested. Opened well and RIH-tied in w/CCL-stopped at 7,208' and dumped cmt. POOH. Pulled inside lubricator and shutin well-bled off pressure and B/0 L/D lubricator. Shut down operation to allow cmt to setup (before closing vent and dumping another 18'of cmt). Hilcorp Alaska, LLC tlikeorp Alaska.LL4: Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date M-11 50-733-20590-00 210-145 11/24/14 12/15/14 Daily Operations: 12/13/14-Saturday Waiting on cement. PJSM w/production & Pollard E-Line crew. P/U lubricator. M/U Run#7(centralizer,wt bar, CCL, centralizer, 2-1/2" LIB). Pulled inside lubricator and M/U to tree. Opened well (203#s-static)- RIH to 7,208'setting down solid,clean P/U. POOH- B/O lub and laid out tool-no impression of pointed vent top (slick btm). M/U Run#8(1.70" CCL, 40' 2-1/2" cmt bailer w/tapered btm). Armed and filled bailer w/8.2 gals of 17#cmt slurry-pulled inside lubricator and M/U to tree-pressured up lub to 200#s w/field gas-opened well. RIH and tied in w/CCL-tagged &dumped cmt at 7,208'- POOH. M/U Run#9 (same as#8). Armed and filled bailer w/8.2 gals of 17#cmt slurry-pulled inside lubricator and M/U to tree-pressured up lub to 200#s w/field gas-opened well. RIH and tied in w/CCL-dumped cmt at 7,202'- POOH. M/U Run#10(same as#9). Armed and filled bailer w/8.2 gals of 17#cmt slurry-pulled inside lubricator and M/U to tree- pressured up lub to 200#s w/field gas-opened well. RIH and tied in w/CCL-dumped cmt at 7,196'- POOH. Shutin well & completely rigged down/packed up Pollard-finished with plugback operation.Waiting on cement. 12/14/14-Sunday Held PJSM w/production & Halliburton E-Line crew. Positioned wireline equipment and rigged up full lubricator w/ grease. Found crossed strands in wireline-re-headed line. M/U 2- 1.70"tungsten wt bars, GR/CCL,6' 2" EHC Idd 6 SPF 60 degree phase w/GeoDynamic Connex 11 grm charges P/N 102494160. Pulled inside lub and tested to 500psi low/ 3,500psi high. Opened well w/60#s FTP. RIH &tagged btm at 7,193' (solid). Correlated to Petra CSP Tie-In Log DPCL(no date-used w/E5 perfs). Logged into position and perfed 6,990-92'. No increase in pressure-initial drop in gas prod but came back to previous level. POOH. Closed swab valve and bled off pressure- broke off lub-laid down tools. M/U 20' 2" EHC Idd 6 SPF 60 degree phase w/same chrgs+GR/CCL-armed gun and pulled inside lub- M/U to tree. Opened well to 61#s FTP (slight increase in gas prod)- RIH &correlated on depth-logged into position and perforated 6,970-991...No increase in pressure-same drop in gas production. POOH. Closed swab valve and bled off pressure-broke off lubricator and laid down tools.; igged Halb off well. Standby to observe well and receive orders. 12/15/14-Monday Received directions from engineering to R/D M/O Halliburton-job finished. SCHEMATIC Steelhead Well M-11 II As Completed: 12/07/2011 As Perfed: 12/14/14 Ili orp:11u4a.1.1.1 Casing&Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM -L 28"Conductor (MD) (ND) ECP Stage Collar 28" Structural 27" Surface 470' 470' 13-3/8" _ 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' a 7" 26 L-80 DWC 6.276 6399' 10283' 8939' '13 3/8"Csg in 17 1/2"Hole 31/2" 9.2 L-80 TC-II 2.992 Surface 3002' 2822' Completion Equipment Information I Item Depth MD Depth TVD OD ID 3-1/2"9.38 TC-II SCSSV 481' 481' 5.176" 2.813" X Profile 3�"SFO-1 Mandrel 1509' 1494' 5.313" 2.867" 3 W'SF0-1 Mandrel 2408' 2316' 5.313" 2.867" Comp II Pkr,4 Iso Pkrs 3'''A"SFO-1 Mandrel 2920' 2750' 5.313" 2.867" ` A-5C Sands 3'''A"X-Profile 2946' 2773' 3.960" 2.813" "T d CompII"HP"Packer 3002' 2822' 8.320" 6.000" '. r 6 B-3, -5 Sands GP Sleeve 3043' 2858' 5.880" 3.750" B-8 Sands 5"Blank Pipe 3061' 2874' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3179' 2979' 6.692" 4.256" r,.. C-1 Sands MSV Screen Sleeve 3231' 3026' 6.692" 3.830' Comp II Sump Packer 8 Ga Wire Wrapped Screen 3238' 3033' 6.692" 4.256" Isolation Packer 3254' 3047' 8.310" 3.830" I GP Sleeve 3260' 3053' 5.880" 3.750" MI Stage Collar 5"Blank Pipe 3277' 3068' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3534' 3306' 6.692" 4.256' N 9 5/8"Csg in 12 Y."Hole MSV Screen Sleeve 3617' 3385' 6.692" 3.830' 8 Ga Wire Wrapped Screen 3624' 3392' 6.692" 4.256' �- — Isolation Packer 3640' 3407' 8.310" 3.830" 9 5/8"x 7"Liner Hanger;17 GP Sleeve 3645' 3412' 5.880" 3.750" MZ Ivy ■ ZXP Liner Top Packer ) 5"Blank Pipe 3663' 3429' 5.000" 4.276" r(' • E Sands 8 Ga Wire Wrapped Screen 3789' 3550' 6.692" 4.256' TTVBP . @iS,-E-7 Sands MSV Screen Sleeve 3857' 3616' 6.692" 3.830' 7,210' ii 8 Ga Wire Wrapped Screen 3964' 3722' 6.692" 4.256' Tagged Fill ,274' Isolation Packer 3880' 3639' 8.310" 3.830" GP Sleeve 3886' _ 3645' 5.880" 3.750" TOC @ 8,286' 5"Blank Pipe 3903' 3661' 5.000" 4.276" Cement Retainer @ 8,491' 8 Ga Wire Wrapped Screen 4004' 3762' 6.692" 4.256" MSV Screen Sleeve 4050' 3807' 6.692" 3.830" Wri ni 8 Ga Wire Wrapped Screen 4057' 3814' 6.692" 4.256" _ _ 7"x 3%"S-3 Packer Isolation Packer 4072' 3829' 8.310" 3.830" 01 IA GP Sleeve 4078' 3835' 5.880" 3.750" - 5"Blank Pipe 4096' 3852' 5.000" 4.276" _ -- 7"x 3 W FB-1 Packer 8 Ga Wire Wrapped Screen 4118' 3874' 6.692" 4.256" INN MSV Screen Sleeve 4171' 3926' 6.692" 3.830" 8 Ga Wire Wrapped Screen 4177' 3932' 6.692" 4.256" .k Comp-Perm II Sump Packer 4184' 3939' 8.125" 6.000" 7"298 LTC-Casing 4188' 3943' 7.000" 6.184" _ is * TOC&Posi-Set#1=8,991' 3-1/2"9.38 TC-Il Tubing 4219' 3974' 3.500" 2.992" 3 1/2 9.38 TC-II Half Muleshoe 6351' 6020' 3.500" 2.920" Swell Packers @ 8,831',9,014',9,491',9,759' Perforation Detail Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Density Status Date,Comment Whr s"re'11' TOC&Posi-Set#1=9,374' (SPF) A-5C 3,198' 3,205' 2,997' 3,003' 14 Open A-SC 3,214' 3,234' 3,011' 3,029' 14 Open •• 1 B-3 3,549' 3,620' 3,321' 3,388' 14 Open -.or: -+t„y. B-5 3,810' 3,848' 3,571' 3,608' 14 Open TOC&PDSi-Set#1=9,510' B-5 3,852' 3,856' 3,611' 3,615' 14 Open B-8 4,032' 4,054' 3,790' 3,811' 14 Open ...n..Poo C-1 4,135' 4,140' 3,891' 3,896' 14 Open C-1 4,143' 4,180' 3,899' 3,935' 14 Open 6,970' 6,992' 6,521' 6,539' 6 Open 12/14/14 ES 7,242' 7,287' 6,734' 6,768' 6 Isolated 11/28/14 7"Liner in 8 W Hole ES 7,447' 7,491' 6,888' 6,920' 6 Isolated 11/28/14 E-7 7,588' 7,595' 6,990' 6,995' 4 Isolated 12/20/2012 F-11 8,946' 8,977' 7,975' 7,997' 6 Isolated MAX HOLE ANGLE=43.9°@ 7,689'MD F-15B 9,270' 9,290' 8,209' 8,223' 6 Isolated TD 10,290'MD/8,945'ND F-16 9,420' 9,440' 8,317' 8,331' 6 Isolated PBTD 8,975'/7,996'ND G-05 9,830' 9,868' 8,613' 8,641' 5 Isolated Updated by:JLL 01/13/15 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable direct inspection of the file. b_ I 0 - L 4-5 Well History File Identifier Organizing(done) Two-sided ill Iliii 1 ❑ Rescan Needed III 111111 Y I I II I III RE AN DIGITAL DATA OVERSIZED (Scannable) Col r Items: ❑ Diskettes, No. ❑ Ma s: reyscale Items: ❑ Other, No/Type: Other Items Scannable by a Large Scanner fopm RI cN ❑ Poor Quality Originals: r �,,� OVERSIZED (Non-Scannable) L2X ❑ Other: E Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: a i• /s/ We Project Proofing 111111111111011111 BY: daalb Date: 31(Q $/iq q /s/ rnio Scanning Preparation q x 30 = -704 + 147 = TOTAL PAGES a D U (Count does not include cover sheet) f BY: Maria _ Date: 4,1 /9, /s/ Production Scanning 1111111111101M Stage 1 Page Count from Scanned File: 3;U / (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: Z YES NO BY: WOO Date:3 a.6" `/L /.., f Stage 1 If NO in stage 1, page(s)discrepancies were ound: YES NO BY: Maria Date: Is/ Scanning is complete at this point unless rescanning is required. 1111111111111111111 ReScanned 11111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIIIIIIIIIIII o E• U) o v a -—. 9 N 0 0M E a) a va a) U �_ E2 rn o E m N Z N N L0 k0 N w .V C 0 7 p p. p IL J c 0) 0 p C T e) 0 °' Y! ccn aZi in 'yp� 30� ,=�a o ° o o '� p o 3 a0 0 o ce g c o •3i_0 o:U > 0- E m E a E I Et m e N �o a), 1) E oy o fij oH9 12 m w > �cc- IXez$0.=Oci > u o I-1- 0 0 1° 0 _ Z c o 0 a? c :? 20 0 O =0 E c Q0 a 0 0 a a O 0 0 E. 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Q co 0 M 7 G) N W J (.0 J -.C- , O / = Z Z Ci. N U 40-- <S) Q W J re Q a Ce v W 0• cn > V J• Q ci o Q o o c y J Oa :° = m () T E aM o s rS 0 u_ ON n oE V M U J QIII z o Ln Ca m za) o 0 Q ' o Q o a Z E Q a) 0 �col z -, 1 TDa) 1 coZ 0 H in a� m o N O d Z -a o N a' G 0) Q cam.. , v o c8 Z m v �• c CO U y E a V) E 0 n 8 I E E a Q 2i 0 co 1 0 0 I' STATE OF ALASKA ALASKA O, .1D GAS CONSERVATION COMMISSION . REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U _ Stimulate U . Other U Recomplete Performed: Alter Casing 9 Pull Tubing 9Perforate New Pool 9 Waiver 9 Time Extension❑ Change Approved Program 9 Operat.Shutdown 9 Perforate 9 , Re-enter Suspended Well ❑ 2.Operator Union Oil Company of California 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 2 Exploratory ❑ 210-145 ' - 3.Address: PO Box 196247,Anchorage,AK 99519 Stratigraphic 9 Service ❑ 6.API Number: T 50-733-20590-00 a0 7.Property Designation(Lease Number): 8.Well Name and Number: /� ADL17594/ADL18730[Steelhead Platform] Trading Bay Unit M-11 • RECEIVED D 9.Field/Pool(s): a �d McArthur River Field/Middle Kenai Gas Pool , DEC 1 Z),1 10.Present Well Condition Summary: 2 Total Depth measured 10,290, feet Plugs measured 8,286 NA SIca Oil&Gas Cons.COn iiiS$IOrd true vertical 8,944 . feet Junk measured N/A feet Anchorage Effective Depth measured 8,286 feet Packer measured 3,002,3,254,3,640,3,880,4,072,4,184 feet true vertical 7,495 feet true vertical 2,822,3,047,3,407,3,639,3,829,3,939 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,432' 13-3/8" 1,432' 1,420' 5,020psi 2,260psi Intermediate 6,618' 9-5/8" 6,618' 6,240' 6,240psi 6,870psi Production Liner 3,884' 7" 10,283' 8,939' 7,240psi 5,410psi 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 3,002' 2,822' 481'(MD) Packers and SSSV(type,measured and true vertical depth) See Schematic See Schematic TC-II SCSSV 481'(TVD) 11.Stimulation or cement squeeze summary: F-11 perforations abandoned via a cement retainer set(418,491'with 9 Bbls of 15.3 ppg Class G cement squeezed below and 10 Bbls dumped on top. TOC subsequently tagged @ 8,286' Intervals treated(measured): High rate water packs performed on the A-5C(3,198'-3,234'),B-3(3,549'-3,620'),B-5(3,810'-3,856'),B-8(4,032'-4,054')and ✓f the C-1 (4,135'-4,180')with 6%KCI brine and 20-40 gravel Treatment descriptions including volumes used and final press.: A-5C 11,553 lbs 20-40 gravel behind screens Q Max 8.2 BPM,PMax 4,000 psi,330 lbs/ft of perfs B-3 4,629 lbs 20-40 gravel behind screens Q Max 8.2 BPM,PMax 4,000 psi,26 lbs/ft of perfs B-5 3,591 lbs 20-40 gravel behind screens Q Max 6.2 BPM,PMax 4,000 psi,25 lbs/ft of perfs B-8 4,929 lbs 20-40 gravel behind screens Q Max 8.2 BPM,PMax 4,000 psi,44 lbs/ft of perfs C-1 2,960 lbs 20-40 gravel behind screens Q Max 8.2 BPM,PMax 4,000 psi,28 lbs/ft of perfs 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 0 0 0 0 Subsequent to operation: N/A _ (B-5 only) 689 0 140 279 13.Attachments: 14.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory 9 Development 9 ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15.Well Status after work: Oil U - Gas U WDSPL U GSTOR 9 WINJ 9 WAG 9 GINJ 9 3USP❑ SPLUG❑ 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 311-303 Contact David Ross Phone:263-7696 Printed Name Timothy C.Branden• • Title Drilling Manager Signature G ? _,W.:-..."" 'L�J Phone 276-7600 Date 12/9/2011 1 l]' 'Chevron r %. Steelhead Platform Well M-11 As Built WI: Dec 7, 2011 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM 28"Conductor (MD) (TVD) 28" Structural 27" Surface 470' 470' ECP Stage Collar 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' 7" 26 L-80 DWC 6.276 6399' 10283' 8939' 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3002' 2822' .i J L 13 3/8"Csg in 17 1/2"Hole Completion Equipment Information Item Depth MD Depth TVD OD ID 3-1/2"9.3# TC-II SCSSV 481' 481' 5.176" 2.813" 3%"SFO-1 Mandrel 1509' 1494' 5.313" 2.867" X Profile 3'/2"SFO-1 Mandrel 2408' 2316' 5.313" 2.867" Comp II Packer 3'/z'SFO-1 Mandrel 2920' 2750' 5.313" 2.867" Isolation Packer 3'/2'X-Profile 2946' 2773' 3.960" 2.813" Comp II"HP"Packer 3002' 2822' 8.320" 6.000" Isolation Packer GP Sleeve 3043' 2858' 5.880" 3.750" Isolation Packer 5"Blank Pipe 3061' 2874' 5.000" 4.276" Isolation Packer 8 Ga Wire Wrapped Screen 3179' 2979' 6.692" 4.256" MSV Screen Sleeve 3231' 3026' 6.692" 3.830' Comp II Sump Packer 8 Ga Wire Wrapped Screen 3238' 3033' 6.692" 4.256" Isolation Packer 3254' 3047' 8.310" 3.830" on Stage Collar GP Sleeve 3260' 3053' 5.880" 3.750" 5"Blank Pipe 3277' 3068' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3534' 3306' 6.692" 4.256' MSV Screen Sleeve 3617' 3385' 6.692" 3.830' 8 Ga Wire Wrapped Screen 3624' 3392' 6.692" 4.256' Isolation Packer 3640' 3407' 8.310" 3.830" 9 5/8"Csg in 12'A"Hole GP Sleeve 3645' 3412' 5.880" 3.750" 5"Blank Pipe 3663' 3429' 5.000" 4.276" . . 9 5/8"x 7"Liner Hanger w/ 8 Ga Wire Wrapped Screen 3789' 3550' 6.692" 4.256' ZXP Liner Too Packer MSV Screen Sleeve 3857' 3616' 6.692" 3.830' .J - `, TnC 5 8288' 8 Ga Wire Wrapped Screen 3964' 3722' 6.692" 4.256' Isolation Packer 3880' 3639' 8.310" 3.830" Cement Retainer @ 8491' GP Sleeve 3886' 3645' 5.880" 3.750" 5"Blank Pipe 3903' 3661' 5.000" 4.276" 7"x 3'A"S-3 Packer 8 Ga Wire Wrapped Screen 4004' 3762' 6.692" 4.256" MINMSV Screen Sleeve 4050' 3807' 6.692" 3.830" 8 Ga Wire Wrapped Screen 4057' 3814' 6.692" 4.256" 7"x 3'A"FB-1 Packer Isolation Packer 4072' 3829' 8.310" 3.830" GP Sleeve 4078' 3835' 5.880" 3.750" 5"Blank Pipe 4096' 3852' 5.000" 4.276" 8 Ga Wire Wrapped Screen 4118' 3874' 6.692" 4.256" Z • 2 MSV Screen Sleeve 4171' 3926' 6.692" 3.830" _ 8 Ga Wire Wrapped Screen 4177' 3932' 6.692" 4.256" Comp-Perm II Sump Packer 4184' 3939' 8.125" 6.000" TOC&Posi-Set#1 =8991' 7"29#LTC-Casing 4188' 3943' 7.000" 6.184" 2 k` Sell Packers @ 3-1/2"9.3#TC-II Tubing 4219' 3974' 3.500" 2.992" 8831',9014',9491',9759' 3 1/2 9.3#TC-II Half Muleshoe 6351' 6020' 3.500" 2.920" TOC&Posi-Set#1 =9374' Perforation Detail 2111.111111.1\ MD(WLM) TVD Zone Density Status Measured Pore (SPF) Pressure(psi) 3198'-3205' 2997'-3003' A-5C 14 Open TOC&Posi-Set#1 =9510' 3214'-3234' 3011'-3029' A-5C 14 Open 3549'-3620' 3321'-3388' B-3 14 Open 2 3810'-3848' 3571'-3608' . B-5 14 Open = 3852'-3856' 3611'-3615' B-5 14 Open 4032'-4054' 3790'-3811' B-8 14 Open 4135'-4140' 3891'-3896' C-1 14 Open 7"Liner in 8''"Hole 4143'-4180' 3899'-3935' C-1 14 Open 8946'-8977' 7975'-7997' F-11 6 Isolated 2730 9270'-9290' 8209'-8223' F-15B 6 Isolated 3175 MAX HOLE ANGLE=43.9°@ 7,689' MD 9420'-9440' 8317'-8331' F-16 6 Isolated 2970 TD 10,290'MD/8,945'TVD 9830'-9868' 8613'-8641' G-05 5 Isolated 2000 PBTD 8,975'/8,016'TVD Chevron . Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion-Reconfigure Major Rig 11/7/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number M-11 507332059000 2101450 Daily Operations 11/8/2011 00:00-11/9/2011 00:00 Operations Summary R/D prepare to skid rig to M-11. Skid rig to west. Begin rigging up E-line. 11/9/2011 00:00-11/10/2011 00:00 Operations Summary Finish R/U E-line, P/T lubricator to 250 psi low/3,000 psi high. RIH w/tubing punch and punch holes from 8,613'to 8,619',POOH and P/U a 2.5"radial cutting torch. RIH and cut pipe @ 8,610'.POOH and UD tool string, R/D E-line. Continue to skid rig. 11/10/2011 00:00-11/11/2011 00:00 Operations Summary Continue to clear decks and skid the rig.Jim Regg w/the AOGCC was given notice of the upcomining BOPE test. 11/11/2011 00:00-11/12/2011 00:00 Operations Summary Finish skiding rig over well M-11. 11/12/2011 00:00-11/13/2011 00:00 Operations Summary Continue to R/U equipment. Fill well with filtered inlet water(FIW). 11/13/2011 00:00-11/14/2011 00:00 Operations Summary Circulate well w/FIW. N/D tree and N/U riser and BOP. 11/14/2011 00:00-11/15/2011 00:00 Operations Summary Continue to R/U BOPE,change out lower pipe rams to 3.5",M/U 5"test joint assembly. Perform shell test to 250 psi low/3,000 psi high.Test annular to 250 psi low/2,500 psi high w/5"pipe.Test remaining BOPE to 250 psi low/3,000 psi high.Jim Regg of AOGCC waived witness for the BOP test. 11/15/2011 00:00-11/16/2011 00:00 Operations Summary Continue to test BOPE, change out annular element, P/T annular w/3.5"pipe to 250 psi low/2,500 psi high. Re-test annular with 5"pipe to 250 psi low/2,500 psi high. Perform acculumaltor test,start 3,100 psi,after closure 1,400 psi w/200 psi build in 20 sec,full recovery in 190 sec. R/D test equipment, M/U landing joint to hanger and circulate well w/FIW. 11/16/2011 00:00-11/17/2011 00:00 Operations Summary Fill well w/FIW, unseat tubing hanger and prepare to pull 3 1/2"tubing. 11/17/2011 00:00-11/18/2011 00:00 Operations Summary POOH and stand back 81 stands of 3 1/2"tubing . UD 12 single jts,SSSV and 4 GLMs.Toubleshoot pipe skate. M/U 7"cement retainer on running tool and TIH on 5"DP to 4138'. Mr.Jim Regg with the AOGCC was given notice of the upcoming cement plug tag via e-mail @ 12:58 PM 11/18/2011 00:00-11/19/2011 00:00 Operations Summary Continue to TIH w/7"cement retainer on 5"DP,set retainer @ 8,491'and test same. P/T annulus to 500 psi. R/U cementing lines and P/T to 1,000 psi low 14,000 psr nlgn. sting Into fetainer and perform injectivity test up to 3 BPM.Mix and pump 19 bbls of 15.3 ppg Class G cement and displace w/fresh water.Squeeze 9 bbls of cement below retainer before reaching-the-max-squeeze pressure of 3.000 psi.Sting out of retainer and dump 10 bbls of cement on top. Pull 4 stands and reverse circulate.TOH and UD retainer running tool. TIH w/22 stands of 3'A"tubing and begin POOH while UD singles. Phoebe Brooks and Jim Regg with the AOGCC were given notice of the upcoming cement tag. 11/19/2011 00:00-11/20/2011 00:00 Operations Summary ' ' _assembly and continue to TIH on 5"DP to 8,200'.Tag Continue to UD 3 2'tubing. P/U 7"cleanout assembly on z and5/8"cleanout as hard cement @ 8,286'w/15K down.CBU and pump wash train while rotating and reciprocating.Short trip 9 5/8"assembly to surface and trip back in hole to 8,286'.Continue to circulate w/FIW. Prepare to displace to 6%KCI brine. 11/20/2011 00:00-11/21/2011 00:00 Operations Summary Pump high vis sweep and displace well to 6%KCI completion bring.Circulate wellbore while close loop filtering.TOH with cleanout assemblies and UD same. 11/21/2011 00:00-11/22/2011 00:00 Operations Summary Perform BOP test,pressure annular to 250psi low/2,500psi high and remaining BOPE to 250psi low/3,000psi high. AOGCC representative John Crisp waived witness for the BOP testa Begin to RIH with 7", 14spf TCP guns with 4-5/8"spacer sections on 5"DP. • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 11/22/2011 00:00-11/23/2011 00:00 Operations Summary Continue to P/U and TIH w/7"TCP assembly.R/U E-line and PT lubricator to 250 psi low/3,000 psi high,RIH w/gamma ray and correlate guns on depth, POOH,stand back E-line and setchamp packer @2,999. R/U E-line and test lubricator to 250 psi low/3,000 psi high, RIH and confirm guns are in place with top shot Cil 3,198'and bottom shot @ 4.180'. R/U nitrogen and bleed lines,apply 500 psi test to annulus and locate packer bypass opening position. Prepare to pressure test treating lines. 11/23/2011 00:00-11/24/2011 00:00 Operations Summary Continue pressure testing hard line w/brine and then N2 to 5,000 psi. Displace brine from workstring w/N2.Close bypass and pressure workstring to 2900 psi w/N2.Continue to pressure workstring_with brine to 3,800 psi to fire 7" 14spf TCP guns. Guns fired @ 15:53 perforating the A-5C(3,198'- , 3,205',3,214'-3,234'), B-3(3,549'-3,620'), B-5(3,810'-3,848',3,852'-3,856'),B-8(4,032'-4,054')and C-1 (4,135'-4,140',4,143'-4,180'). Bullhead DP volume of brine and monitor losses. Pump Clean Plug LCM pill.Balance well while taking returns through choke, monitor well. Unseat packer and begin TOH w/TCP assembly. 11/24/2011 00:00-11/25/2011 00:00 Operations Summary Continue TOH w/TCP assembly and L/D same.All shots fired.P/U and M/U post perf clean out assembly and TIH on 5"DP.Wash and ream through each perf interval twice with no increased torque observed. 11/25/2011 00:00-11/26/2011 00:00 Operations Summary TIH w/post perf cleanout assembly to 6,370'. Drop 3.125'drift and TOH and L/D BHA. Notify AOGCC of upcoming BOP test by phone and e-mail.TIH w/2,132'of 3%"tail pipe,M/U 1 jt of 7"casing,sump packer,setting tool, RA sub and crossovers and TIH.Space out packer 2'deep from intended setting depth.Matt Herrera w/AOGCC waived witness to BOP test. R/U E-line with gamma ray and CCL tool and P/T lubricator to 250 psi low/3,000 psi high. 11/26/2011 00:00-11/27/2011 00:00 Operations Summary RIH with gamma ray CCL tool string and correlate sump. acker on depth. POOH and R/D wireline. P/U workstring 2'to place sump packer 0 4 184' Establish circulation and P/T surface line to 3,000 psi. Drop setting ball and set packer.Test packer by slacking off and picking up 20K.Pressure up work string and blow ball seat. P/U 2'and place seals in packer bore. P/T below thesacker to 1,000 psi.TOH and L/D BHA. Test all BOPE to 250 psi low/3,000 psi high including the annular with 3 Yz'and 5"test joints. Perform accumulator test;starting pressure 3,025 psi,after closure-1,750 psi,200 psi build in 30 sec,full build in 135 sec. R/D test equipment and install wear bushing. Prepare to P/U and run MST gravel pack system. Begin running in the hole with the C-1 assembly. 11/27/2011 00:00-11/28/2011 00:00 Operations Summary Finish running thg C-1 GP assembiy_and P!T same to 450 psi. P/U and RIH w/the B-8, B-5,B-3 and A-5C GP assemblies and consecutively P/T all assemblies to 450 psi prior to moving to the next assembly. PIT entire assembly to 500 psi prior to P/U and M/U the service tool string and hanging off inside the GP assembly. Begin running the service tool assembly inside the GP assembly on 2 7/8"tubing. 11/28/2011 00:00-11/29/2011 00:00 Operations Summary Continue to RIH w/2-7/8"inner string. M/U test sub and P/T entire GP assembly to 500 psi.M/U 9 5/8"production packer and TIH w/completion to 4,128'. R/U GP manifold and lines,stab into sump packer,drop packer setting ball,set and test production packer 0_3,12Q1'. Pressure up casing to 2,000_Esi to initiate set of isolation.packers.Pressure up DP to 4,500 psi and release setting tool. P/U and verify release.Reverse setting ball back to surface. Recover ball. P/U and slack off to open C-1 screen sleeve and confirm communication. P/U to reverse position and pickle workstring to crossover port with 10 bbls of 10%HCI acid and reverse back to slop tank. Dump seals and monitor well. 11/29/2011 00:00-11/30/2011 00:00 Operations Summary P/T GP treating,lineaso 250 psi low/5,000 psi high,set C-1 isolation packer @ 4,072'w/4,000 psi,spot 5%HCI acid on perfs,perform step rate injection test w/no indication of frac rate.Perform HRWP on the C-1 sand @ 8.2 BPM w/1 ppa sand.SancLaut..t4.4 Q0Q,p occurred with 2.916 lbs behind screens.Reversed+/-1,500 lbs of sand and re-stress pack and calculate 28 lbs/ft of perforation in the formation and 25'of blank covered.Close C-1 GP &Screen sleeves,dump seals and P/T completion integrity to 1,000 psi.Open B-8 screen valve,set isolation packer @ 3,880'to 4,000 psi,spot 5%HCI acid on perfs,perform step rate injection test and calculate 5.4 BPM frac rate w/BHFP of 2,536'.Perform HRWP on the B-8 sand a8.2 BPM w/1 ppa sand.Sand out to 4,000 psi occurred with 4 929 lbs behind screens,.Reversed+/-10 lbs of sand and re-stress pack and calculate 44 lbs/ft of perforation in the formation and 101'of blank covered.Close B-8 GP&Screen sleeves,dump seals and P/T completion integrity to 1,000 psi.Open B-5 screen valve and space out to set isolation packer. • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 11/30/2011 00:00-12/1/2011 00:00 Operations Summary Set B-5 isolation packer @ 3,640'w/4,000 psi,spot 5 bbls of 5%HCI acid on perfs,perform step rate injection test and calculate—3_9 BPM frac rate.w/ BHFP of 2,080'.Perform HRWP on the B-5 sand @ 6.2 BPM w/1 ppa sand.Sand out to 4,000 psi occurred with 1591 lbs behind screens.Reversed+/- 1,050 lbs of sand and re-stress pack and calculate 25 lbs/ft of perforation in the formation and 30'of blank covered.Close B-5 GP&Screen sleeves, dump seals and P/T completion integrity to 1,000 psi.Open B-3 screen valve and space out to set isolation packer.Set B-3 isolation packer @ 3,254'w/ 4,000 psi,spot 5 bbls of 5%HCI acid on perfs,perform step rate injection test and calculate 3.8 BPM frac rate w/BHFP of 1,646 psL Perform HRWP on the B-3 sand @ 8.2 BPM w/1 ppa sand.Sand out to 4,000 psi occurred with 4,629 lbs behind screens.Reverse out and re-stress pack and calculate 26 lbs/ft of perforation in the formation and 32'of blank covered.Close B-3 GP&Screen sleeves,dump seals and P/T completion integrity to 1,000 psi. f4 Open A-5C screen valve and space out to spot 5 bbls of 5%HCI acid on perfs.perform step rate injection test and calculate 3 4 BP.M._fraarate w/BHFP of 1,743 psi. Perform HRWP on the A-5C sand @ 8.2 BPM w/1 ppa sand.Sand out to 4,000 psi occurred with 11,553 lbs behind screens. Reverse out and re-stress pack and calculate 330 lbs/ft of perforation in the formation and 45'of blank covered.Close A-5C GP&Screen sleeves,dump seals and P/T completion integrity to 1,000 psi. 12/1/2011 00:00-12/2/2011 00:00 Operations Summary TOH standing back 5"DP, L/D 2-7/8"inner string and shifting tools.Pull wear bushing and R/U to run 3-1/2"tubing.TIH w/3-1/2"tubing string with GLMs @ 2,919',2,407'and 1,502'and SSSV @ 481'. Space out land hanger,M/U contol line through hanger and test to 5,000 psi, land hanger and RILDS. Test tubing seals and hanger to 1,000 psi for 5 mins. P/T hanger seals to 250 psi low/5,000 psi high for 10 minutes.Set BPV and secure SSSV. 12/2/2011 00:00-12/3/2011 00:00 Operations Summary Continue to R/D completion equipment and L/D remaining 3-1/2"tubing. Prepare to skid rig. Gas lifting well. 12/3/2011 00:00-12/4/2011 00:00 Operations Summary No M-11 operations. 12/4/2011 00:00-12/5/2011 00:00 Operations Summary R/U slickline w/MSV-O shifting tool set to position#1, P/T lubricator to 250 psi low/3,000 psi high. RIH and shift the A-5C MSV-O to the open position. POOH and inspect tool, RIH for confirmation run. POOH and R/D slickline. Begin gas lifting well. 12/5/2011 00:00-12/6/2011 00:00 Operations Summary Flow test well.Shut-in well. R/U slick-line and P!T lubricator to 250 psi low/3,000 psi high. RIH w/position#2 shifting tool and attempt to shift the B-3 production sleeve open.Confirm valve shifted by_running back through with the tool string. R/D slick-line. 12/6/2011 00:00-12/7/2011 00:00 Operations Summary ` R/U slickline and P/T lubricator to 250 psi low/3,000 psi high. RIH with position#2 shifting tool and shift the B-3 production sleeve open. POOH and invert tool and RIH to shift sleeve closed to confirm sleeve function.POOH and invert tool and RIH again to shift sleeve open. POOH and inspect tools, R/D slickline. 12/8/2011 00:00-12/9/2011 00:00 Operations Summary R/U slick-line and P/T lubricator to 250 psi low/3,000 psi high. RIH with position#1 keys on shifting tool and make 4 attempts to open the B-3 production sleeve @ 3,617'w/o sussess.Change to position#2 keys and RIH to open the sleeve @ 3,617'after 2nd attempt. Turn well over to production. 12/9/2011 00:00-12/10/2011 00:00 Operations Summary Flowing well. 12/10/2011 00:00-12/11/2011 00:00 Operations Summary Production flowing well.M/U 1 3/4"tool string w/braided line brush and RIH to brush through sleeves @ 3,857',4,049'and 4,170', POOH.RIH with#2 keys to close the B-3 sleeve @ 3,615'.Put well on test to confirm the sleeve closed. M/U#3 keys and RIH to open the B-5 production sleeve A 3,860', pressure dropped from 450 psi to 190 psi confirming the sleeve opened. Turn well over to production. 12/11/2011 00:00-12/12/2011 00:00 Operations Summary Production flowing well. R/U slick-line and P!T lubricator to 250 psi low I 3,000 psi high. RIH w/#3 keys to close the B-5 sleeve @ 3,855', POOH. STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMI.,,,ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other❑ — Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac 0 Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 210-145 -' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20590-00 41 E C E iVED 7.Property YDesi nation(Lease Number): 8.Well Name and Number: ADL 18730 Steelhead Platform - Trading Bay Unit M-11 - DEC 14 2012 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G Pool R'lO�V� 11.Present Well Condition Summary: Total Depth measured 10,290 feet Plugs measured N/A feet true vertical 8,945 feet Junk measured N/A feet Effective Depth measured 8,975 feet Packer measured See Schematic feet true vertical 7,996 feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,432' 13-3/8" 1,432' 1,420' 5,020 psi 2,260 psi Intermediate Production 6,618' 9-5/8" 6,618' 6,240' 6,870 psi 4,760 psi Liner 7" 68 1,432' 1,420' 7,240 psi 5,410 psi 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 3,002' 2,822' Packers and SSSV(type,measured and true vertical depth) Packers(See Schematic) TC-II SCSSV 481'(MD)/481'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1,632 21 180 162 Subsequent to operation: 0 2,238 21 210 108 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ GSTOR ❑ WINJ ❑ WAG El GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature j '171 ---"- - _ Phone 907 777-8420 Date 12/14/2012 iCtQr-,QAC. rir-r` 1 Pi ono 'I-CM J /L•ie./7/ Hilcorp Alaska, LLC HacorpAlaska.LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-11 50-733-20590-00 210-145 11/30/2012 12/2/2012 Daily Operations: 11/30/12-Friday Rig up lubricator.Pressure test to 250 psi low and 2,500 psi high.Tubing pressure 310 psi. RIH with 2-1/2"x5'bailer and tag obstruction at 4,261'RKB. Pushed obstruction out the tubing tail at 6,351'RKB.Went on down hole and tagged at 8,274'RKB. POOH. RIH with 2-1/2"x10'spent dummy guns down to 7,700'RKB.POOH.Rig down lubricator. 12/01/12-Saturday No operations to report. 12/02/12-Sunday Rig up lubricator.Pressure test to 250 psi low and 2,500 psi high.RIH with 2-1/2"x10'(7'loaded)HC,4 spf,60 deg phase,CCL/GR,1 wt.bar and tie into composite log provided by Radu Girbacea.Spot perf gun from 7,588'to 7,595'per Final Approved Perf Request Form by R.Girbacea.Tubing pressure 310 psi.Fired guns and didn't see any pressure increase.POOH.All shots fired.Rig down off well.Turn well over to production. Steelhead Platform SCHEMATIC Well: M-11 Completed: 12/07/2011 nil.orp%6-1.0.1,1.1. Casing&Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM 28"Conductor (MD) (TVD) A_111 ,ift ECP Stage Collar 28" Structural 27" Surface 470' 470' - 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' 7" 26 L-80 DWC 6.276 6399' 10283' 8939' 13 3/8"Csg in 17 1/2"Hole 3 1/2" 9.2 L-80 TC-Il 2.992 Surface 3002' 2822' J Completion Equipment Information Item Depth MD Depth TVO OD ID 3-1/2"9.3#TC-Il SCSSV 481' 481' 5.176" 2.813" 31A"SF0-1 Mandrel 1509' 1494' 5.313" 2.867" X Profile 3""SF0-1 Mandrel 2408' 2316' 5.313" 2.867" INIIIIM Comp II Packer 3'A"SF0-1 Mandrel 2920' 2750' 5.313" 2.867" '--- Isolation Packer 3'"X-Profile 2946' 2773' 3.960" 2.813" Comp II"HP"Packer 3002' 2822' 8.320" 6.000" Isolation Packer GP Sleeve 3043' 2858' 5.880" 3.750" Isolation Packer 5"Blank Pipe 3061' 2874' 5.000" 4.276" Isolation Packer 8 Ga Wire Wrapped Screen 3179' 2979' 6.692" 4.256" MSV Screen Sleeve 3231' 3026' 6.692" 3.830' IIIIIIIIIIIIIIIIIIII� Comp II Sump Packer 8 Ga Wire Wrapped Screen 3238' 3033' 6.692" 4.256" Isolation Packer 3254' 3047' 8.310" 3.830" GP Sleeve 3260' 3053' 5.880" 3.750" MI - Stage Collar 5"Blank Pipe 3277' 3068' 5.000" 4.276" 8 Ga Wire Wrapped Screen 3534' 3306' 6.692" 4.256' 9 5/8"Csg in 12'/."Hole MSV Screen Sleeve 3617' 3385' 6.692" 3.830' 8 Ga Wire Wrapped Screen 3624' 3392' 6.692" 4.256' 9 5/8"x 7"Liner Hanger w/ Isolation Packer 3640' 3407' 8.310" 3.830" ZXP Liner Top Packer GP Sleeve 3645' 3412' 5.880" 3.750" 5"Blank Pipe 3663' 3429' 5.000" 4.276" -211 8 Ga Wire Wrapped Screen 3789' 3550' 6.692" 4.256' E7 MSV Screen Sleeve 3857' 3616' 6.692" 3.830' 8 Ga Wire Wrapped Screen 3964' 3722' 6.692" 4.256' Tagged Fill @ 8,274' Isolation Packer 3880' 3639' 8.310" 3.830" GP Sleeve 3886' 3645' 5.880" 3.750" TOC @ 8,286' 5"Blank Pipe 3903' 3661' 5.000" 4.276" Cement Retainer @ 8,491' 8 Ga Wire Wrapped Screen 4004' 3762' 6.692" 4.256" MSV Screen Sleeve 4050' 3807' 6.692" 3.830" 8 Ga Wire Wrapped Screen 4057' 3814' 6.692" 4.256" 7"x 3'A"S-3 Packer Isolation Packer 4072' 3829' 8.310" 3.830" . . GP Sleeve 4078' 3835' 5.880" 3.750" 5"Blank Pipe 4096' 3852' 5.000" 4.276" 7"x 3'/"FB-1 Packer 8 Ga Wire Wrapped Screen 4118' 3874' 6.692" 4.256" MSV Screen Sleeve 4171' 3926' 6.692" 3.830" %1. 8 Ga Wire Wrapped Screen 4177' 3932' 6.692" 4.256" Comp-Perm II Sump Packer 4184' 3939' 8.125" 6.000" 7"29#LTC-Casing 4188' 3943' 7.000" 6.184" 3-1/2"9.3#TC-II Tubing 4219' 3974' 3.500" 2.992" TOC&Posi-Set#1 =8,991' 3 1/2 9.38 TC-II Half Muleshoe 6351' 6020' 3.500" 2.920" Sell Packers @ = 8,831',9,014',9,491',9,759' Perforation Detail • ;.,-, TOC&Posi-set#1=9,374' Density Status Measured {.; El MD(WLM) ND Zone (SPF) Pore Pressure (psi) - 3198'-3205' 2997'-3003' A-5C 14 Open x, . : .. . t TOC&Posi-Set#1=9,510' 3214'-3234' 3011'-3029' A-5C 14 Open II Z1 3549'-3620' 3321'-3388' 8-3 14 Open •� _ 3810'-3848' 3571'-3608' B-5 14 Open 000 3852'-3856' 3611'-3615' 8-5 14 Open 4032'-4054' 3790'-3811' 8-8 14 Open 4135'-4140' 3891'-3896' C-1 14 Open 7"Liner in 8%"Hole 4143'-4180' 3899'-3935' C-1 14 Open 7588'-7595' 6990'-6995' E-7 4 Open 8946'-8977' 7975'-7997' F-11 6 Isolated 2730 -_ MAX HOLE ANGLE=43.9°@ 7,689'MD 9270'-9290' 8209'-8223' F-15B 6 Isolated 3175 TD 10,290'MD/8,945'TVD 9420'-9440' 8317'-8331' F-16 6 Isolated 2970 PBTD 8,975'/7,996'TVD 9830'-9868' 8613'-8641' G-05 5 Isolated 2000 �� a Ti' A (-0 -q- SEAN PARNELL,GOVERNOR __=A0) \\ ALASKA OIL A1VD GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Timothy C. Brandenburg Drilling Manager 0 -- Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Middle Kenai Gas Pool, Trading Bay Unit M-11 Sundry Number: 311-303 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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. 1l Chair DATED this )0day of October, 2011. Encl. ., nio 10-") RECEIVED STATE OF ALASKA SEP 2 9 2011 ALASKA OIL AND GAS CONSERVATION COMMISSIONP-13 '"'\ APPLICATION FOR SUNDRY APPROVALS Alaska Oil&Gas Cons. Commission 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool El Repair Well❑ Change 419APIWgram ❑ Suspend❑ Plug Perforations Q Perforate Q 7 Pull Tubing Q • Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate Q , Alter Casing❑ Other:Recomplete - Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Union Oil Company of California Development Q- Exploratory 0 210-145 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 196247,Anchorage,AK 99519 50-733-20590-00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? ,Yes ❑ No 0 Trading Bay Unit M-11 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL17594/ADL18730[Steelhead Platform] McArthur River Field/ Middle Kenai Gas Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,290 , 8,944 ' 8,975 7,996 8,991',9,374'&9,510' 8,975' Casing Length Size MD ND Burst Collapse Structural Conductor 470' 28" 470' 470' Surface 1,432' 13-3/8" 1,432' 1,420' 5,020psi 2,260psi Intermediate 6,618' 9-5/8" 6,618' 6,240' 6,870psi 4,760psi Production Liner 3,884' 7" 10,283' 8,939' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,946-8,977 7,975-7,997 3-1/2" 9.2#/L-80 8,903 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Model 85-40 S-3,Model FB-1 Production and 3-1/2"WellStar TRSV TCII 8,639(MD)-7,751(TVD),8,661(MD)-7,761(TVD)and 435(MD&TVD) 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory ❑ Development ❑., • Service 0 14.Estimated Date for 15.Well Status after proposed work: 11/11/2011 Commencing Operations: Oil ❑ Gas ❑., • WDSPL ❑ Suspended ❑ 16.Verbal Approval: N/A Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Ross Phone: 263-7696 Printed Name Timothy C.Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 9/26/2011 _ COMMISSION USE ONLY �j Conditions of approval: Notify Commission so that a representative may witness Sundry Number: v I 1 -3D3 Plug Integrity ❑ BOP Test iyi, Mechanical Integrity Test ❑ Location Clearance ❑ Other: .3OU 0 v. +''q,^Z ,r,..\_‘)r.\ �ck,t%.,,\. ..z. Subsequent Form Required: l © q 0 L APPROVED BY Approved b ,10,/ OCT / QC I 1 ,y 1fOMMISSIONER THE COMMISSION Date: /0160 / 1 1 • Chevron 0 St dead Platform ,, Weil M-11 (As Built) Sept 21, 2011 2KB to TBG Head=78' Casing&Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM 28"Conductor (MD) (TVD) 28" Structural 27" Surface 470' 470' No 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' ECP Stage Collar 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' 7" 26 L-80 DWC 6.276 6399' 10283' 8939' 3 1/2" 9.2 L-80 TC-Il 2.992 Surface 8903' 7943' 13 3/8"Csg in 17 1/2"Hole , Completion Equipment Information Item Depth MD Depth TVD OD ID , ECP Stage Collar 420' 420' 3'/2'WellStar TRSV TCII 435' 435' _ 2.813" 3'/2"SFO-1 Mandrel 1588' 1569' 5.313" 2.867" 3'/2'SFO-1 Mandrel 3102' 2910' _ 5.313" 2.867" 3'h"SFO-1 Mandrel 4229' 3983' _ 5.313" 2.8.67" Cement stage collar 4369' 4121' 3'/z'SFO-1 Mandrel 5255' 4993' 5.313" 2.867" 3'/2"SFO-1 Mandrel 6024' 5730' 5.313" 2.867" ,t 3'/z'SFO-1 Mandrel 6793' 6380' 5.313" 2.867" 31/2"SFO-1 Mandrel 7530' 6949' 5.313" 2.867" 3 W SFO-1 Mandrel 8135' 7386' 5.313" 2.867" Stage Collar 31/2"SFO-1 Mandrel 8582' 7710' _ 5.313" 2.867" X Nipple 8631' 7746' 3.950" 2.810" MB Model 85-40 S-3 Packer 8639' 7751' 5.870" 3.927" tt X-Nipple 8648' 7758' 3.960" 2.810" Model FB-1 Production Packer 8661' 7767 5.950" 4.000" X Profile 8694' 7791' 3.950" 2.813" Swell Packer 8831' 7891' 9 5/8"x 7"Liner Hanger w/ Swell Packer 9014' 8025' 1 ZXP Liner Too Packer Swell Packer 9491' 8368' _ Swell Packer 9759' 8562' J 9 5/8"Csg in 12'/:'Hole WLEG 9749' 8554' 7"x 3'i°S-3 Packer Perforation Detail MD(WLM) TVD Zone Density Status Measured Pore (SPF) Pressure(psi) IM J 7"x 3'/"FB-1 Packer 9830'-9868' 8613'-8641' G-05 5 Isolated 2000 9420'-9440' 8317'-8331' F-16 6 Isolated 2970 9270'-9290' 8209'-8223' F-15B 6 Isolated 3175 8946'-8977' 7975'-7997' F-11 6 Open 2730 * Fill Tag @ 8975' Logging Detail TOC&Posi-Set#1=8991'E\-:\ Hole LWD/MWD Wire Mud Logging Notes Section Line _ �: Sell Packers @ 17'/2 gMWD,GR/RES Gas On Site Geologist 8831',9014',9491',9759' 12'/4 Triple Combo Mudlog On Site Geologist 8'/2 Triple Combo,Form. Pressure Mudlog On Site Geologist TOC&Posi-Set#1=9374' = Cementing Information 13513Description Volume Density(ppg) Yield(ft3/sx) Notes 4 TOC&Posi-Set#1 =9510' (bbls) Surface 1st stg 179/111 13.0/14.0 1.95/1.60 Bumped Plug Eil: Surface 2nd stg 285 13.0 1.95 Full Returns Intermediate 1s'stg 228 14.0 1.95 Bumped Plug Intermediate 2nd stg 324 13.0 1.95 Bumped Plug Production single stage 175.5 15.8 1.18 Packed off at L.H. 7"Liner in 8%"Hole MAX HOLE ANGLE=43.9°@ 7,689' MD TD 10,290'MD/8,944'TVD PBTD 8,975'/7,996'TVD Well Detail DRAWN RV. DR 9/21/11 Chevron Steelhead Platform , 1%110 Well M-11 (Proposed) %. Sept 26, 2011 Casing&Tubing Detail 28"Conductor BTM BTM SIZE WT GRADE CONN MIN ID TOP (MD) (TVD) r_ ECP Stage Collar 28" Structural 27" _ Surface 470' 470' II13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' 7" 26 L-80 DWC 6.276 6399' 10283' 8939' 3 1/2" 9.2 L-80 TC-II 2.992 Surface 3000" 13 3/8"Csg in 17 1/2"Hole Completion Equipment Information Item Depth MD Depth TVD OD ID 3-1/2"9.3# TC-II SCSSV +/-435' +/-435' 5.176" 2.813" 3''A"SFO-1 Mandrel +/-900' +/-900' 5.313" 2.867" Comp II Packer 3'/2"SFO-1 Mandrel +/-1900' +/-1863' 5.313" 2.867" MP- Isolation Packer 3'/2"SFO-1 Mandrel +/-2970' +/-2793' 5.313" 2.867" all OK Comp II"HP"Packer +/-3000' +1-2820' 8.320" 6.000" -.. Isolation Packer 5"Blank Pipe +1-3058' +/-2871' 5.000" 4.276" won 'f ter.:" Isolation Packer Screen Communication System +/-3178' +/-2979' 6.692" 3.830" Isolation Packer Isolation Packer +/-3250' +/-3044' 8.310" 3.830" 5"Blank Pipe +/-3272' +1-3064' 5.000" 4.276" Comp II Sump Packer Screen Communication System +/-3534' +/-3306' 6.692" 3.830" X Profile Isolation Packer +1-3635' +1-3402' 8.310" 3.830" no me Stage Collar 5"Blank Pipe +1-3657' +1-3423' 5.000" 4.276" Screen Communication System +1-3795' +1-3556' 6.692" 3.830" Isolation Packer +1-3876' +1-3635' 8.310" 3.830" 5"Blank Pipe +1-3898' +1-3656 5.000" 4.276" Screen Communication System +1-4008' +1-3766' 6.692" 3.830" Isolation Packer +1-4070' +/-3827' 8.310" 3.830" s 5/8"Csg in 12'h"Hole 5"Blank Pipe +/-4093' +/-3849' 5.000" 4.276" It Screen Communication System +/-4118 +/-3874' 6.692" 3.830" 9 5/8"x 7"Liner Hanger w/ 5"Blank Pipe +/-4182' +/-3937' 5.000" 4.276" ZXP Liner Too Packer Comp-Perm II Sump Packer +1-4188' +/-3943' 8.125" 6.000" vittle, 2 ` Tor, a5no' 7"29#LTC-Casing +/-4192' +/-3947' 7.000" 6.276" Cement Retainer @ 8550' 3'/2'X-Profile +/-4233' +/-3987' 3.960" 2.813" 3-1/2"9.3#TC-Il Tubing +/-4235' +/-3988' 3.500" 2.992" # y 3 1/2 9.3#TC-II Half Muleshoe +/-6354' +1-6023' 3.500" 2.920" rr"' - 7"x 3'/:"S-3 Packer Perforation Detail 7"x 3'/z"FB-1 Packer MD(WLM) TVD Zone Density Status Measured Pore (SPF) Pressure(psi) +1-3190'-+/-3240' +1-2989'-+l-3035' A-5 14 Open 585 c ti +1-3548'-+/-3626' +1-3320'+/-3394' B-3 14 Open 323 :ii +/-3810'-+/-3866' +/-3571'-+/-3625' B-5 14 Open 355 + +/-4030'-+/-4060' +/-3788'-+/-3817' B-8 14 Open 550 t+'1 vitt: +/-4135'-+/-4180' +/-3891'-+/-3935' C-1 14 Open 480 TOC&Posi-Set#1=8991' 8946'-8977' 7975'-7997' F-11 6 Isolated 2730 9270'-9290' 8209'8223' FF-_1156B 6 Isolated 3175 Sell Packers @ 9420'-9440' 8317'-8331' F-16 6 Isolated 2970 8831',9014',9491',9759' 9830'-9868' 8613'-8641' G-05 5 Isolated 2000 ""a"".* : TOC&Posi-Set#1=9374' Logging Detail ...1 Hole LWD/MWD Wire Mud Notes Section Line Logging ""' `' `I TOC&Posi-Set#1=9510' 17 1/2 gMWD,GR/RES Gas On Site Geologist 12'/. Triple Combo Mudlog On Site Geologist 8'/2 Triple Combo,Form. Pressure Mudlog On Site Geologist Cementing Information 7"Liner in 8'/2"Hole Description Volume Density(ppg) Yield(ft3/sx) Notes (bbls) Surface 1st stg 179/111 13.0/14.0 1.95/1.60 Bumped Plug Surface 2nd stg 285 13.0 _ 1.95 Full Returns MAX HOLE ANGLE=43.9°@ 7,689' MD Intermediate 1s`stg 228 14.0 1.95 Bumped Plug TD 10,290'MD/8,945'TVD Intermediate 2"1 stg 324 13.0 1.95 Bumped Plug PBTD 8,975'/8,016'TVD Production single stage 175.5 15.8 1.18 Packed off at L.H. Chevron Trading Bay Unit IWO ' Well # M-11 9/14/11 OBJECTIVES: • Cut and pull the existing production tubing and abandon the F-11 sand. • Complete the A-5, B-3, B-5, B-8 and C-1 sands with a single trip multi-zone GP system. • Run 3 1/2" completion tubing string with gas lift design. Current BHP: 3,453psi @ 7975' TVD Max Downhole Pressure: 3,453psi @ 7975' TVD (Based on initial pressure of the F-11 sand) MASP: 2936 psi (Based on a pressure gradient of 0.0648 psi/ft of TVD) M-11 RE-COMPLETION PROCEDURE SUMMARY 1.1. R/U E-line, P/T lubricator to 250/3000 psi and RIH with tubing punch and punch holes from +/- 8,603'- +/- 8,609' and POOH. 1.2. RIH with a radial cutting torch and cut the tubing at +/- 8,600', POOH. R/D E-line. 1.3. N/D Tree and N/Ult3OPE.4." `°(.N 1.4. Circulate well over to filtered inlet water, pump a LCM pill if required. 1.5. Pull 3 1/2' completion string from +/- 8,600'. 1.6. P/U a 7" K-1 cement retainer and stinger and TIH to set retainer @ +/- 8,550' MD 1.7. Mix and pump +/-12 bbls of+/- 15.3 ppg class G cement, squeeze +/- 8 bbls below the retainer, sting out and dump +/- 4 bbls on top of the retainer. Reverse excess cement, POOH, and WOC. 1.8. RIH with wellbore cleaning BHA to +/- 8,600'. 1.9. Circulate well over to filtered 6% KCL, POOH. 1.10. TCP perforate the A-5, B-3, B-5, B-8 and C-1 sands listed on the proposed schematic. 1.11. RIH with cleanout BHA to +/-4,500', POOH 1.12. P/U 9 5/8" sump packer and tubing tail assembly and RIH, R/U E-line and RIH to correlate packer on depth @ +/- 4,188' set packer, POOH 1.13. RIH with the single trip, multi-zone GP assembly and stab into the sump packer at +/- 4,188'. 1.14. Drop the packer setting ball and hydraulically set production packer at +/- 3,000'. 1.15. Open the C-1 interval MSV and MS GP sleeve, set isolation packer. 1.16. Perform HRWP on the C-1 interval and reverse out any excess sand. 1.17. Close the MS GP Sleeve and MSV for the C-1 interval. 1.18. P/U and repeat steps 1.15 through 1.17 for the B-8, B-5, B-3 and A-5 intervals 1.19. P/U 3 1/2" tubing with pop lock seal assembly and ratchet M/S, gas lift mandrels and SSSV, RIH, space out tubing, land tubing in hanger. 1.20. ND BOPs and NU Tree and test same 250psi low/ 3,000psi high. 1.21. Turn well over to production jFP <o�v Wa" ire ��' �� hrrur. e F r/ sc�J 1491 O 6v� Q/ w, r� -�-� 4'",� 1- ScifrA ni9r C� an fi avt' Ric fracirciA, 1 , Chevron Steelheau Platform 2011 Workover and New Drill 07/7/2011 A Rig floor 1 Bottom ofd p pan l� JiJ 6.75' ?" X 16"for air boot leeve, 19' in length At Tuboscope 10.92' 26.23' Moot pool deck It rig floor tit- it•iit•ti - y 4.54' ' Hydrilo GK 13 5/8-5000 ti ,I.:1,ii. n: -- C ey 'l4 — 4.67' r' Beo$t . is on bottom r 'ii—. Top of Moonpool A Moonpool deck top©55.95' III 'r'" ' ' WINO deck 55.38' 9.60' t.ri iri in Total BOP assembly I 'I` .�a �(' {+tf }fl 2.26' A Nil 'Pt Ip110 IV III CIM 2.83' lil lil':i til iii 1.25' tlttil III I!'t!l ✓ I CO O1 . 3.86'flange above rig sub grating O O A Rig sub grating Upp Sr Wellhead Room to Rig Sub 21.00 Grating 23.47' (- ( )2) 5.08'clamp above floor • Upper wellhead room floor A 18.83' Well lead floor to Upp>r Wellhead Room 22.88' F Top of Vetco wellhead©9.13' r IF ir Chevron Francisco Castro Chevron North America Exploration and Production -- Technical Assistant 3800 Centerpoint Dr. Suite 100 b Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE April 13, 2011 To: AOGCC Shartzer, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WELL LOG TYPE LOG DATE INTERVAL 8 CD LOGGED UNE TBU M-06 PERFORATION RECORD 1-Mar-2011 8932-8966 X X TBU M-06 PERFORATION RECORD 16-Mar-2011 9072-9112 X X TBU M-06 PERFORATION RECORD 24-Feb-2011 9235-9245 X X TBU M-06 PERFORATION RECORD 28-Feb-2011 9278-9351 X X TBU M-06 PERFORATION RECORD 23-Feb-2011 9150-9438.5 X X TBU M-06 COMPLETION RECORD 23-Feb-2011 8803-9450 X X TBU M-06 COMPLETION RECORD 22-Feb-2011 8757-9233 X X TBU M-11 PERFORATION RECORD 10-Jan-2011 9270-9290 X X TBU M-06 PERFORATION RECORD 27-Feb-2011 9210-9230 X X TBU M-06 TEMPERATURE-PRESSURE-GR-CCL 27-Feb-2011 9112-9406.4 X X a0,-odq Q059 ' A 'r-) Please acknowledge receipt by signing and returning one copy of this tri u a r'=A to �7 263 7828. Received By: Date: Apo Ali"; Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 �tf � Ufa Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE March 7, 2011 To: AOGCC Shartzer, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WELL LOG TYPE LOG DATE INTERVAL & CD LOGGED LINE TBU M-11 COMPLETION RECORD POSITIVE DISPLACEMENT 01/04/2011 9000-9536 X X DUMP BAILER TBU M-11 PRODUCTION PROFILE 01/19/2011 76-8976 X X TBU M-11 COMPLETION RECORD DUMP BAILER RECORD 01/14/2011 8990-9000 X X TBU M-11 COMPLETION RECORD MPBT POSISET PLUG 01/08/2011 9200-9400 X X TBU M-11 PERFORATION RECORD ZONE F11 01/15/2011 8946-8977 X X TBU M-11 COMPLETION RECORD TUBING CUTTER 12/30/2010 9150-9400 X X TBU M-11 COMPLETION RECORD 01/11/2011 9000-9536 X X TBU M-11 COMPLETION RECORD MPBT POSISET PLUG 01/04/2011 9000-9536 X X TBU M-11 COMPLETION RECORD DUMP BAILER 01/11/2011 9020-9040 X X TBU M-11 PERFORATION RECORD 01/06/2011 9000-9536 X X j ' 11 0/0 u x ,51 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: Chevron Christopher A. Ruff Chevron North America • Petroleum Engineer Exploration and Production MidContinent/Alaska SBU 3800 Centerpoint DR., Suite 100 P.O. Box 196247 Anchorage, 99519-6247 Telel90777 263 7677 Fax 907 263 7828 Email ruffca@chevron.com February 21, 2011 `� Mr. Dan Seamount, Commissioner REM Y ED Alaska Oil and Gas Conservation Commission �E� 01� 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 l &GHQ Cow Commission Form 10-421 Anchorage For Well M-11, McArthur River Field Dear Commissioner Seamount: Attached is Form 10-421 "Gas Well Open Flow Potential Test Report" for the newly completed Well M-11 on the Steelhead Platform. Please contact Christopher Ruff at 907-263-7677 if you have any questions. Sincerel Christopher A. Ruff Petroleum Engineer Cc: Dave Whitacre Attachments Form 10-421 MidContinent/Alaska SBU/Chevron North America Exoloration and Production www_chevron.com STATE OF ALASKA ALASKA viL AND GAS CONSERVATION COMMISSIL._ ` GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1a.Test: U Initial U Annual U Special 1b.Type Test: U Stabilized U Non Stabilized U Multipoint ❑ Constant Time ❑ Isochronal ❑ Other 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Union Oil Company of California 1/15/2011 210-145 3.Address: 6.Date TD Reached: 12.API Number: PO Box 196247,Anchorage,AK 99519 November 28,2011 50- 733-20590-00 4a.Location of Well(Governmental Section): 7.KB Elevation(ft): 13.Well Name and Number: Surface: 1048 FNL,457'FWL,Sec 33,T9N,R13W,SM 160' Steelhead M-11 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 1065'FNL,293'FWL,Sec 33,T9N,R13W SM 8,976'MD(7,996'TVD) McArthur River Field Total Depth: 9.Total Depth(MD+TVD): Middle Kenia Gas Pool 700'FSL, 1678'FWL,Sec 28,T9N,R13W,SM 10,290'MD(8,945'TVD) 4b.Location of Well(State Base Plane Coordinates): 10.Land Use Permit: 15.Property Designation: Surface: x- 214073 y-2499455 Zone- 4 ADL 18730 TPI: x- 213909 y-2499442 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 215333 y-2501173 Zone- 4 perforated casing 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19.Perforations: From To 7" 26 6.276 10283 F 11 8946' 8977' 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 3-1/2" 9.2 2.992 8903 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 8661 NA NA NA 24a.Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): Q Tubing ❑ Casing 150 F° 2730 psia @ Datum 7811 TVDSS 14.7 psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: NA NA 0.5855 0.44 5.169 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice Size(in.) Size(in.) psig Hw F° psig F° psig F° Hr. 1. X 1075 62 0 NA 0.5 2. X 840 62 0 NA 0.5 3. X 750 62 0 NA 0.5 4. X 640 62 0 NA 0.5 5. X 460 62 0 Na 4 Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) hwPm Pressure Gravity Factor Rate of Flow Fb or Fp Pm Factor Fg FactorPQi Mcfd 1. 4500 2. 4700 3. 4800 4. - 4900 5. 5000 Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. 1.61 522 1.522 0.87 2. 1.26 522 1.522 0.89 3. 1.13 522 1.522 0.9 Critical Pressure • 666.4 4. 0.96 522 1.522 0.91 _ Critical Temperature 343 5. 0.69 522 ' 1.522 . 0.93 RBDMS FEB 2 4 2011 - 0-74r Pc 1734.7 pct 3009184.09 Pt 2082 pf2 4335775.514 No. . Pt Pte Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Pse Pe-Ps2 1. 1089.7 1187446.1 1821738 1298 ' 1684227.6 1324956.534 I 1740 I 3027600 64964 2. 854.7 730512.09 2278672 1014 1027992 1981192.118 1450 2102500 64965 3. 764.7 584766.09 2424418 906 820272.5 2188911.593 1360 1849600 95820 4. 654.7 428632.09 2580552 774 598862.87 2410321.224 1230 1512900 141892 5. 474.7 225340.09 2783844 559 312740.42 2696443.667 1060 1123600 191685 25. AOF (Mcfd) 5,544 n 0.5 Remarks: I hereby certi hat,. e foreg•ing is true and correct to the best of my knowledge. Signed _ ,///��� Title Petroleum Engineer Date 2/21/2011 WV ,A"-, DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ -I hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= ddimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(ND) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gas 0 SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20nnc 25.105 20AAc 25.110 Development Q Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Union Oil Company of California Aband.: 1/15/2011 210-145 3.Address: 6.Date Spudded: 13.API Number: PO Box 196247,Anchorage,Alaska,99519 11/3/2011 50-733-20590-00 ''. 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1048 FNL,457'FWL,Sec 33,T9N,R13W,SM 11/28/2011 Trading Bay Unit M-11 Top of Productive Horizon:1065'FNL,293'FWL,Sec 33,T9N,R13W SM 8.KB(ft above MSL): 160 15.Field/Pool(s): GL Ground(ft MSL): McArthur River Field Total Depth:700'FSL,1678'FWL,Sec 28,T9N,R13W,SM 9.Plug Back Depth(MD+TVD): 8,976'MD(7,996'ND) Middle Kenai Gas Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x- 214073 y-2499455 Zone- 4 10,290'MD(8,9457VD) ADL 18730[Steelhead Platform] TPI: x- 213909 y-2499442 Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 215333 y-2501173 Zone- 4 435'MD(435'TVD) N/A 18.Directional Survey: Yes U No U 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 MC 25.050) 185' (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/ND: GR/Resistivity,GR/Resistivity/Neutron/Density,Formation pressure,USIT,Mud log N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 28-32 X-56 Surface 491' Surface 491' Driven N/A / 179bbl 13.0ppg lead/111 bbl ,,,,,- 13-3/8" 68 L-80 Surface 1,432' Surface 1,420' 17-1/2" 14.0 ppg class G cement tail (stage 1)&285bb1 13.Oppg class G cement(stage 2) 228bb1 14ppg class G cement 9 5/8" 47 L-80 Surface 6,618' Surface 6,240' 12-1/4" (stage 1)&324bb1 13.Oppg 7 class G cement(stage 2) 7" 26 L-80 6,399' 10,283' 6,062' 8,940' 8-1/2" 176bbl 15.8ppg class G cement(single stage) 24.Open to production or injection? Yes 0 No❑ If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 2.5"PJ omega 6spf 60°guns 8,946'-8,977'MD(7,974'-7,997'TVD) 3-1/2" 8,903' 8,639'MD(7,7511VD) 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 1/15/2011 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 1/21/2011 24 Test Period . :0,0 5640 690 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 566 psi 385 psi 24-Hour Rate . 0 5640 690 N/A 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No E Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summa f ter (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and I I .Fin~ / r( r , .. ; ?('lii [ i 1 RBDMS FEB 16 2 ii noss 0ss caMloluitso Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base See attached formation top Information Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Flynn 263-7824 Printed Name: Timothy C.Brandenburg Title: Drilling Manager Signature: ,1 _� Phone: 276-7600 Date: 2/15/2010 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 b: 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 and Ground Level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. 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Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UW ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Drill and Complete Drill and 10/25/2010 12/31/2010 Complete Primary Wellbore Affected Wellbore UWI Well Permit Number M-11 507332059000 2101450 Daily Operations 10/25/2010 00:00-10/26/2010 00:00 Operations Summary R/U Diverter and stack 10/26/2010 00:00-10/27/2010 00:00 Operations Summary Continue rig up 10/27/2010 00:00-10/28/2010 00:00 Operations Summary Continue rig up 10/28/2010 00:00-10/29/2010 00:00 Operations Summary P/U 5"DP,continue rig up 10/29/2010 00:00-10/30/2010 00:00 Operations Summary Continue rig up 10/30/2010 00:00-10/31/2010 00:00 Operations Summary Mix spud mud,test all mud lines. Notified AOGCC(Bob Noble)24 hrs prior to diverter test,witnessed waived@ 15:30 hrs 10/31/2010 00:00-11/1/2010 00:00 Operations Summary Mix spud mud,Test diverter system and recorded closing times. Annular closed in 30 sec.Knife opened in 12 sec.Test all mud lines to 5000 psi,All personnel to beach for Safety meeting. 11/1/2010 00:00-11/2/2010 00:00 Operations Summary All day safety meeting in Kenai.Crew return to platform at 20:00 hrs. 11/2/2010 00:00-11/3/2010 00:00 Operations Summary M/U BHA,cleanout conductor to 480'MD, Perform diverter and abandonment drills,M/U Drilling BHA.MW:9.2 ppg. 11/3/2010 00:00-11/4/2010 00:00 Operations Summary Clean out conductor F/450'MD. POOH, P/U BHA#1,TIH Directionally drill w/17.5"bit F/450'MD to 1002'MD. MW:9.1ppg 11/4/2010 00:00-11/5/2010 00:00 Operations Summary Directionally Drill F/1002'MD to 1440'MD.TD of Surface hole.Circulate bottoms up, POOH,RIH w/conductor cleanoout tool.MW:9.5PPG 11/5/2010 00:00-11/6/2010 00:00 Operations Summary P/U 13 3/8"shoe track and run 13 3/8"68#L-80 Casing to 1432'MD. MW:9.5 ppg 11/6/2010 00:00-11/7/2010 00:00 Operations Summary Circulate casing until hole clean, R/U cement lines and pump 1st stage cement. 179 bbls, 13.0 ppg(518 sks)of class G cement and 111 bbls, 14 ppg (387 sks)of class G cement. Bumped plug, inflated ECP and opened stage collar at 420'MD.Circulated and reported cement after 30 bbls pumped. Pump 2nd stage cement:285 bbls 13 ppg(812 sks)full returns to surface(15%excess), R/D diverter lines.MW:9.5 ppg. Gave 24 hrs notice to AOGCC of upcoming BOP test 11/7/2010 00:00-11/8/2010 00:00 Operations Summary N/U BOP's,AOGCC(Lou Grimalldi)waived witness of BOP test due to weather Test BOP's with 250psi low/3000psi high,Build new mud system. 11/8/2010 00:00-11/9/2010 00:00 Operations Summary P/U Directional BHA,TIH,Mill out ECP packer @ 418'MD,TIH,Tag cement @ 1340'MD,Test surface casing to 1500 psi for 30 min. Good test.Mill out shoe track, Displace to Gem GP mud system.MW:9.00 ppg. 11/9/2010 00:00-11/10/2010 00:00 Operations Summary Drill out w/12-1/4"bit to 1460'MD,circulate and condition mud,perform FIT to 13.0 EMW Test good,Directionally drill ahead F/1460'MD to 3128'MD. Aquire formation pressures at 1650'MD,2135'MD and 2612'MD. MW:9.3ppg no losses 11/10/2010 00:00-11/11/2010 00:00 Operations Summary Continue to directionally Drill F/3128'to 3434'MD.Aquire formation pressure test at 3295'MD.Short trip to shoe,Continue drilling ahead F/3295'MD to 3691'MD.MW:9.3 ppg, No lossess Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 11/11/2010 00:00-11/12/2010 00:00 Operations Summary Drill ahead F/3691'to 4620'MD. Take Formation Tests at 3589'MD,3650'MD,3641'MD,3834'MD,3934'MD,4034'MD.MW:9.2ppg 11/12/2010 00:00-11/13/2010 00:00 Operations Summary Drill ahead F/4620'MD to 4734'MD, POOH for bit, UD BHA, Formation Pressure test aquired @ 4167'MD, MW:9.20ppg 11/13/2010 00:00-11/14/2010 00:00 Operations Summary Change out BHA,TIH, Ream F/4274'MD to 4320'MD, Ream F/4450'MDto 4734'MD, Drill ahead F/4734'MD to 5016'MD, MW:9.3PPG. 11/14/2010 00:00-11/15/2010 00:00 Operations Summary Drill ahead F/5018'MD to 6331'MD,Aquire Formation Pressure Tests @ 4998'MD,5324'MD,MW:9.3 PPG 11/15/2010 00:00-11/16/2010 00:00 Operations Summary Continue Drilling Ahead in 12.25"hole F/6331'MD to 6626'MD,TD of Intermediate section.Aquire Formation Pressure Tests @ 6373'MD.Circulate and condition hole,POOH to run 9 5/8"casing.MW:9.2 ppg. 11/16/2010 00:00-11/17/2010 00:00 Operations Summary Continue POOH,Circulate at shoe,wait on weather,MW:9.30ppg 11/17/2010 00:00-11/18/2010 00:00 Operations Summary POOH, UD Drilling assembly,RIH w/9 5/8"47#L-80 casing.MW:9.35ppg 11/18/2010 00:00-11/19/2010 00:00 Operations Summary Cont. running casing and land hanger at 6618'MD.MW:9.35 ppg. 11/19/2010 00:00-11/20/2010 00:00 Operations Summary Circulate hole clean,Pump stage 1:228 bbls(800 sx)14.0 class G cement, bump plug,open stage collar,circulate hole clean reported 70 bbls cement in returns,pump stage 2:324 bbls(900 sx)class G cement, Bump plug,close stage collar,flush and rig down cement lines., Install packoff. Notify AOGCC of upcoming BOP test. 11/20/2010 00:00-11/21/2010 00:00 Operations Summary Rig up and test BOP's 250/1000 Annular,250/3000 Rams,choke kill lines.All tests held for 5min. No failures to report. Install wear bushing,M/U 8.5" drilling BHA.Witness of test was waived by Jim Regg due to weather not being able to fly helicopter to platform. 11/21/2010 00:00-11/22/2010 00:00 Operations Summary TIH with Drilling BHA, Drill stage collar @ 4366'MD,TIH,Tag Float collar @ 6532'MD,Test Casing to 3000psi for 30 min.Good test. Drill casing shoe at 6618'MD. Drill F16618'MD to 6646'MD. Perform FIT test to 13.0 EMW with MW of 9.25 ppg. Drill 8.5"x 9"hole F/6646'MD to 7091'MD. MW:9.30 ppg 11/22/2010 00:00-11/23/2010 00:00 Operations Summary Drill ahead in 8.5"x 9"0 hole F/9091'MD to 8005'MD. MW:9.30ppg. 11/23/2010 00:00-11/24/2010 00:00 Operations Summary Drill 8.5"x 9.0 hole F/8005'MD to 8034'MD. POOH for bit,Change out BHA components,TIH. MW 9.30 ppg. 11/24/2010 00:00-11/25/2010 00:00 Operations Summary Continue drilling F/8039'MD to 8687'MD, POOH to 6500'MD for washout.MW:9.25ppg 11/25/2010 00:00-11/26/2010 00:00 Operations Summary TIH,Drill ahead F/8687'MD to 9209'MD. Perform Formation pressure tests @ 8942'MD,8956'MD MW:9.25ppg 11/26/2010 00:00-11/27/2010 00:00 Operations Summary Continue drilling ahead F/9209'MD to 9399'MD. Aquire Formation pressure test @ 9266'MD.MW:9.25 ppg 11/27/2010 00:00-11/28/2010 00:00 Operations Summary Continue Drilling ahead 9399'MD to 10150'MD. Aquire Formation pressure tests @:9342'MD,9414'MD,9440'MD,3322'MD,9824'MD,9846'MD. MW: 9.35ppg 11/28/2010 00:00-11/29/2010 00:00 Operations Summary Continue Drilling from 10150'MD to TD of production interval at 10290'MD.Circulate hole clean,short trip to shoe at 6600'MD.TIH to TD circulate hole clean.MW:9.35 PPG 11/29/2010 00:00-11/30/2010 00:00 Operations Summary POOH, UD BHA, R/U to run liner, RIH with liner to 1390'MD,Wait on weather. MW:9.30ppg. Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 11/30/2010 00:00-12/1/2010 00:00 Operations Summary Continue to RIH with 7"26#L-80 liner from 1,390'MD to 10,289'. MW:9.3ppg. 12/1/2010 00:00-12/2/2010 00:00 - Operations Summary Continue to condition mud for cement job, PT cement lines to 5000 psi. Pumped 50 bbls of 12.5 ppg Mud Push followed by 175.5 bbls 15.8 ppg cement at 4.5 BPM and 650 psi. Returns began surging after mud push exited the shoe.At 120 bbls of displacement pressured up to 3000 psi with surging returns, hanger set at 6399'with shoe at 10282'.Continued to pump with no losses until 164 bbls.Switched to cement pump and pumped 80 bbls at 2.3 BPM and 4300 psi w/o returns. Bumped plug and held 4800 psi for 3 mins,tested floats(held ok). Released from hanger set ZXP, circulated with no • mud push or cement to surface.TOH and lay down liner running tool. 12/2/2010 00:00-12/3/2010 00:00 Operations Summary M/U test joint and R/U test equipment. Change out lower rams from 7"to 3 1/2"rams. Test annular 200/1000 psi and 3 1/2"pipe rams 200/3000 psi and .,.- chart same. L/D test joint, install wear bushing,service iron roughneck. P/U and TIH with WBCT assemblies while cleaning pit system and surface equipment. 12/3/2010 00:00-12/4/2010 00:00 Operations Summary Mix Hi-Vis spacer and displace drilling mud with 68 bbls of spacer and FIW. Circulate 4000 bbls of FIW up to 11.5 BPM. Continue to clean pits and surface equipment. 12/4/2010 00:00-12/5/2010 00:00 Operations Summary Continue to circulate caustic and Baraclean pills through low and high pressure mud system.Continue to clean pits.Mix and pump chemical train ;40 bbls of 2 ppb caustic,40 bbls Baraclean and 40 bbls N-Vis at 8 BPM. 12/5/2010 00:00-12/6/2010 00:00 Operations Summary Continue to circulate wash train at 8 BPM, pills returned at 540 bbls displace. Short trip to 6274' ,cleaned upper brush and magnets recovered metal plus 2 pieces of rubber.TIH to 10189'and tagged w/no fill. Circulated well 4 BU at 11.5 BPM while rotating and reciprocating pipe. Pumped 36 bbl N-Vis spacer and displaced well to 6%KCI w/2.1 gal per 10 bbls Inflo-250. Tested casing to 3000 psi and charted same(good test).TOH removing torque reducers and cleaning WBCT assemblies L/D same. Recovered metal from 7"magnets. RU logging equipment. 12/6/2010 00:00-12/7/2010 00:00 Operations Summary R/U e-line equipment and RIH with USIT logging assembly, logging up from 10180'to surface.TOC determined to be 8680', RID e-line equipment and R/U completion tongs and handling equipment. P/U 38'of 4 5/8"TCP guns and TIH with lower 3 1/2"completion assembly, Positioned the DP RA tag at 8588'DPM. R/U e-line equipment and begin RIH with gamma ray to correlate guns on depth. 12/7/2010 00:00-12/8/2010 00:00 Operations Summary Continue RIH w/gamma ray tool,correlation indicated top shot was 27'deep. POOH with logging tools in order to adjust pipe depth. Re-log hole for depth correction confirmation,top shot confirmed to be at 9830'WLM. POOH and L/D logging tools and R/D e-line equipment. Drop packer setting ball and pump down to seat at 1 BPM. Pressure up to 1500 psi and set FB-1 packer at at 8656'DPM. DPM to WLM correction= 12.54'. Pressured up DP to 3000 psi and tested backside to 1000 psi(good test). Rotate and release from packer pressure up to 3000 psi to shear ball seat. TOH with DP and setting tool and L/D same. Pull wear bushing and R/U tubing handling equipment.TIH with upper 3 1/2"completion string(to 6397'TOL at 24:00) 12/8/2010 00:00-12/9/2010 00:00 Operations Summary Continue running upper 3 1/2"9.2#L-80 completion,tagged packer at 8655',Could not stab seals, Made a total of 8 rotations while working pipe up and down,still unable to stab seals.The decision was made to pull the completion. Pulled out of hole toSSSV and L/D same,continued POOH to 7888'and found control line parted and 9 bands missing. Recovered 97.5'of control line at 7280'and 21' at the CIS. L/D CIS Total control line left in hole=596.5' and 48 bands 12/9/2010 00:00-12/10/2010 00:00 Operations Summary -- - -- Continue to rig up 3 1/2"handling equipment.Stand back 3 1/2"tubing from 7151', inspect and L/D GLMs, seal assembly in good shape but mule shoe had 3 set down gouges. R/U BOP test equipment.Tested BOP equipment to 250psi low/3000psi high,all tests recorded. No failures reported.Test witness waived by Jim Regg of AOGCC. R/U slick-line and begin running in hole with 8.52"gauge ring and junk basket runs. 12/10/2010 00:00-12/11/2010 00:00 Operations Summary Continue to make 31 more slick-line fishing runs utilizing ,wire grabs,junk baskets and magnets,total recovery at 24:00=26 whole bands+3"and 1" piece. Bands remaining in hole 21 3/4" 12/11/2010 00:00-12/12/2010 00:00 Operations Summary Continue slick line fishing with wire grabs, magnets and junk boxes.Total recovery at 06:00 hrs=32 bands+3"and 1"piece. Bands remaining in hole 15 3/4. M/U and TIH with reverse basket on DP to 6298'above the TOL,dropped ball and circulate at 10 BPM.Continue TIH washing down, passed through TOL at 6397'with no indications.At 7375'observed a 150 psi pressure increase and a 200 psi increase at 8387'. Tagged TOP lightly at 8655 ciculate at 10 BPM for 15 mins. TOH to 6302',slip and cut drill line. • Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 12/12/2010 00:00-12113/2010 00:00 Operations Summary Continue to slip and cut drill line and service rig components.TOH with reverse basket, UD and inspect same. Recover 13 additional whole bands. Total bands recovered at 6:00 hrs=45 whole bands+3"and 1"piece. 2 3/4"band remaining in hole. M/U reverse basket and TIH to 6298'. Lost inboard bearing on Baylor Brake. Install FOSV and secure well. Discuss plan forward with town. Perform LOTO and prepare for brake repair. 12/13/2010 00:00-12/14/2010 00:00 Operations Summary Continue removing and working on Baylor brake. Waiting on bearings from Houston, 12/14/2010 00:00-12/15/2010 00:00 Operations Summary Removed,cleaned and replaced high drum clutch on draw works. Removed bearing race from Balylor Brake shaft and cribbed up Baylor Brake for new bearing installation. Waiting on bearings from Houston. 12/15/2010 00:00-12/16/2010 00:00 Operations Summary Shut down for rig repair. 12/16/2010 00:00-12/17/2010 00:00 Operations Summary Shut down for rig repair. 12/17/2010 00:00-12/18/2010 00:00 Operations Summary Rig Repair,TIH F/6298'MD to 8482'MD,circulate, POOH,TIH w/slickline to clean junk from hole w/magnets and junk baskets. 12/18/2010 00:00-12/19/2010 00:00 Operations Summary UD slickline, RIH w/packer seal assembly on 3 1/2"tubing,stab seal assembly, M/U and land hanger,Attempted and failed tubing pressure test to 3000psi.R/U slickline with tubing plug to attempt to find tubing leak. 12/19/2010 00:00-12/20/2010 00:00 Operations Summary RIH w/tubing plug,no leak found, Pull hanger off seat,POOH w/3 1/2"9.2#L-80 tubing and seal assembly. 12/20/2010 00:00-12/21/2010 00:00 Operations Summary Continue POOH w/3 1/2"tubing, RIH w/seal assmbly on Drillpipe, Stab seal assembly. Attempted to pressure test tubing to 3000psi and failed. Assumption is that production packer is leaking. POOH with seal assmbly. R/U seal assmbly w/ S-3 production packer on 3 1/2"tubing and RIH. Pressure test tubing while tripping in hole. 12/21/2010 00:00-12/22/2010 00:00 Operations Summary Stab in seal assembly,trip in on slickline,retrieve standing valve,land tubing hanger,test voids 250/5000 psi test good.RIH set prong on slickline, pressure up and set S-3 production packer at 8,639'.Test tubing to 3000 psi,good test.POOH w/slickline. 12/22/2010 00:00-12/23/2010 00:00 Operations Summary R/D slick-line,Set BPV,UD 5"and 3-1/2"DP,Prepare to N/D BOPs 12/23/2010 00:00-12/24/2010 00:00 Operations Summary Continue to UD 5"DP, Begin N/D BOPs and warm stacking of rig. 12/24/2010 00:00-12/25/2010 00:00 Operations Summary Finish N/D BOPs,N/U production tree and test same.Test neck seal 250/5000 for 30 min,good test,Test tree 250/5000 psi for 30 min.good test.Turn well over to production,continue warm stacking rig. 12/27/2010 00:00-12/28/2010 00:00 Operations Summary No rig activity.Production gas lifting well,R/U drop bar lubricator and P/T same 300/2500 psi for 5 min.good test. 12/28/2010 00:00-12/29/2010 00:00 Operations Summary No rig activity,Pressure up tubing to 950 psi with gas to achieve 1500 psi at the firing head. Drop bar,guns did not fire. R/U slick-line and P/T lubricator to 2500 psi. RIH to fish drop bar, stacket out @ 8643',worked through to 8660', POOH 1st attempt no recovery. RIH w/same BHA to 9100'tag 3 times worked down to 9733', POOH 2nd attempt no recovery. 12/29/2010 00:00-12/30/2010 00:00 Operations Summary Fishing for TCP drop bar with slick-line,stacked out @ 9733'and POOH with a 40 lb over pull until+/-3300', no recovery of fish at surface. P/T lubricator to 2500 psi and RIH with same tool to 9700'indicating the guns had released and perfed 9830'-9868'. Tubing pressure increased to 976 psi and fluid level indicated at 7910'while POOH. R/D slick-line. 12/30/2010 00:00-12/31/2010 00:00 Operations Summary R/U slick-line P/T lubricator to 2500 psi and RIH w/2.72"GR,tagged fluid level @ 7030'and top of fish(gun assembly)@ 10067'wlm POOH. Bled tubing pressure from 945 psi to 60 psi and RIH with GR,tagged fluid level @ 4840',POOH and R/D slick-line. Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 12/31/2010 00:00-1/1/2011 00:00 Operations Summary R/U E-line and P/T lubricator to 2500 psi.RIH w/2.5"Power Cutter and correlate cutter on depth @ 9220'wlm,cut tubing and RIH to tag fish @ 9546' wlm, POOH, R/D E-line 1/4/2011 00:00-1/5/2011 00:00 Operations Summary R/U E-line and P/T lubricator to 250/2500 psi,RIH w/7"Posi-Set plug and correlate bottom of plug on depth @ 9545.5'w/top of plug @ 9537',set plug POOH and L/D setting assembly. Re-head E-line and M/U 40'dump bailer, RIH to dump 1st run of cement on top of 7"Posi-set plug. Fluid level tagged @ 4730'wlm 1/5/2011 00:00-1/6/2011 00:00 Operations Summary Continued to dump bailer 7 runs of 16.9 ppg cement on top of 7"posi-set plug set @ 9536'RKB. Fluid level on final run encountered @ 4914'RKB. Prepare to perf the F-16 sand. 1/6/2011 00:00-1/7/2011 00:00 Operations Summary WOC,gas lifted well.Shut down gas lift and R/U dummy gun with pressure/temperature tool,P/T lubricator 250/2500 psi and RIH to locate fluid level @ 9140',and TOC @ 9510', POOH and L/D dummy gun assembly.M/U 20'of 2.5"Power Jet Omega guns 6 spf 60degree phasing,pressure up well to 1000 psi and RIH w/guns. 1/7/2011 00:00-1/8/2011 00:00 Operations Summary Continue RIH to perforate the F-16 sand,correlated guns on depth and perforated for production from 9420'-9440'WLM,monitor well pressure and POOH with spent guns and L/D same.Tubing pressure increase 146 psi in two hours. Gas lifted well and allow well to equalize. Mobilize e-line crew and prepare for posi-set plug and dump bailer runs. Rest crews while flow testing well. 1/8/2011 00:00-1/9/2011 00:00 Operations Summary R/U e-line and pressure test lubricator to 250/2500 psi, RiH w/7"posi-set plug,correlated and set plug @ 9400'wlm. Made 7 dump bailer runs to dump 16.9 ppg cement on top of the 7"posi-set plug.M/U pressure/temeperature tool and RIH,locate fluid level @ 4260', POOH 1/9/2011 00:00-1/10/2011 00:00 Operations Summary WOC.Gas lifted well and pressure tubing to 950 psi.R/U e-line and P/T Ilubricator to 250/3500 psi. RIH with 2.5"dummy gun w/pressure/temperature tool, locate fluid level @ 7144'and TOC @ 9374'POOH and L/D dummy gun.M/U 20'of 2.5"Power Jet Omega guns 6 spf 60 degree phasing. 1/10/2011 00:00-1/11/2011 00:00 Operations Summary RIH w/2.5"Power Jet Omega guns,6 spf,60 deg phasing and correlate guns on depth,perforate the F-15B sand for production @ 9270'-9290'wlm. POOH and L/D perf assembly,turn well over to production, and flow tested well. R/U e-line and RIH w/2.5"Power Cutter and correlate on depth,cut tubing @ 8903'wlm. RIH and set down @ 9100',tool string stuck,worked tool string. 1/11/2011 00:00-1/12/2011 00:00 Operations Summary Continue to work stuck e-line tools,decesion made to disconnect with electric release,POOH,M/U 7"posi-set plug assembly, P/T lubricator to 250/2500 psi,RIH with 7"posi-set and position btm of plug @ 9050'wlm,set plug w/top @ 9040'wlm,POOH.M/U 2 1/8"dump bailer and perform a total of 5 runs to dump 16.9 ppg cement on 7"posi-set plug. 1/12/2011 00:00-1/13/2011 00:00 Operations Summary Continue with bailer runs#7 to drop 16.9ppg cement on 7"Posi-Set plug @ 9040'. POOH and L/D bailer cement in place at 04:10. Rest crews and begin gas lifting well at 22:00 1/13/2011 00:00-1/14/2011 00:00 Operations Summary Continue gas lifting well,pressure well to 950 psi. R/U e-line and RIH with P/T tool and dummy gun and tag fluid level @ 7430'and TOC @ 9008'. POOH and L/D dummy gun and P/U 18',2.5"Power Jet Omega perf gun 6 spf 60 deg phasing and RIH,fluid level rising,consult town,monitor well on 1 hr intervals; 10:20 fluid @ 7160', 11:20 @ 7112', 12:20 @ 7076', 13:20 @ 7030'. POOH disarm and L/D perf gun. Bleed 9 5/8"annulus to 400 psi,R/U to perform lube and bleed operation.Begin lube and bleed operation at 22:00 1/14/2011 00:00-1/15/2011 00:00 Operations Summary Finish lube and bleed operation, R/U e-line and RIH to tag fluid level @ 390',tbg pressure 0 psi. POOH and R/U dump bailer, RIH and tag cement @ 9006',2'higher. Dumped 3 loads of cement on top of existing cement plug. Cement in place @ 13:30, POOH and L/D bailer,WOC 1/15/2011 00:00-1/16/2011 00:00 Operations Summary WOC,start gas lifting well @ 11:00. R/U e-line and RIH w/dummy gun and P/T tool,tag fluid level @ 8275'and TOC @ 8993', Bleed tbg.pressure to 250 psi.2nd fluid tag @ 8054',wait 40 minutes,3d fluid tag @ 8046'wait 40 minutes 4th fluid tag @ 8045.5', POOH L/D dumy gun and M/U 18',2.5" Power Jet Omega,6 spf 60 deg phasing gun. Pressure well to 945 psi and RIH,tag fluid level @ 8135'and TOC @ 8993',correlate guns on depth and perforate the F-11 sand for production from 8959'-8977'. Instant increase in pressure observed.POOH. 1/16/2011 00:00-1/17/2011 00:00 Operations Summary RIH and perf with 2.5"Power Jet Omega 6spf 60 deg phasing guns from 8946'to 8959'. RD e-line.Production flow testing well. Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface U M ChevNo Original RKB(ft) Water Depth(ft) M-11 TRADING BAY UNIT M-11 5073320590 MS0124 79.82 185.00 Daily Operations 1/17/2011 00:00-1/18/2011 00:00 Operations Summary R/U slick-line M/U 1.94"GR BHA, P/T lubricator to 250/2500 psi. RIH with well flowing,tag fill @ 8989', POOH.M/U Press/Temp memory tool and RIH to 8940' 1/18/2011 00:00-1/19/2011 00:00 _ Operations Summary Finish logging w/Press/Temp tool,POOH R/D slick-line download data. 1/19/2011 00:00-1/20/2011 00:00 Operations Summary RU Eline. Pressure test lubricator 250psi low/2500psi high. Perform pressure temperature survey to 8,976',POOH R/D Eline.Turn well over to production. Chevron elhead Platform Well M-11 (As Built) %. Jan 20, 2011 Casing &Tubing Detail SIZE WT GRADE CONN MIN ID TOP BTM BTM (MD) (TVD) 28" Structural 27" Surface 491' 491' 13-3/8" 68 L-80 BTC 12.415 Surface 1432' 1420' 9-5/8" 47 L-80 BTC-M 8.681 Surface 6618' 6240' RKB to TBG Head=78' 7" 26 L-80 DWC 6.276 6399' 10283' 8940' 3 1/2" 9.2 L-80 TC-II 2.992 Surface 8903' 7943' SSSV Completion Equipment Information 28"Conductor Item Depth MD Depth TVD OD ID 1 ECP Stage Collar ECP Stage Collar 420' 420' 3%"WeIIStar TRSV TCII 435' 435' 2.813" 3'/s"SFO-1 Mandrel 1588' 1569' 5.313" 2.867" 3'/2"SF0-1 Mandrel 3102' 2910' 5.313" 2.867" 3'/2"SFO-1 Mandrel 4229' 3983' 5.313" 2.867" Cement stage collar 4369' 4123' 3'/2"SFO-1 Mandrel 5255' 4993' 5.313" 2.867" 13 3/8"in 17'/,"Hole 3''/2'SFO-1 Mandrel 6024' 5730' 5.313" 2.867" 3%"SFO-1 Mandrel 6793' 6380' 5.313" 2.867" .v /I 3'/z'SFO-1 Mandrel 7530' 6948' 5.313" 2.867" 3'/z'SFO-1 Mandrel 8135' 7385' 5.313" 2.867" 3'/2'SFO-1 Mandrel 8582' 7710' 5.313" 2.867" fl X Nipple 8631' 7745' 3.950" 2.810" I Model 85-40 S-3 Packer 8639' 7751' 5.870" 3.927" ® 1 11 Stage Collar `$ >t, X-Nipple 8648' 7757' 3.960" 2.810" Model FB-1 Production Packer 8661' 7767' 5.950" 4.000" • TOC 5450' X Profile 8694' 7791' 3.950" 2.813" Swell Packer 8831' 7890' ko - Swell Packer 9014' 8023' Swell Packer 9491' 8368' 9 5/8"Casing in 12 W Swell Packer 9759' 8561' Hole WLEG 9749' 8554' '/ owt on 9 5/8"x 7"Liner hanger w/ z- ZXP liner top packer Perforation Detail MD(WLM) TVD Zone Density Status Measured Pore (SPF) Pressure(psi) 9830'-9868' 8613'-8640' G-05 5 Isolated 2000 7"x 3%"S-3 Production . 9420'-9440' 831 T-8331' F-16 6 Isolated 2970 9270'-9290' 8209'-8223' F-15B 6 Isolated 3175 2730 idg �' 7"x X Nipple 8946'-8977' 7974'-7997' F-11 6 Open a ® Swell packers @ 8831',9014',9491',9759' Fill Tag 7 Logging Detail @ 8976' TOC&Posi-Set#3=8993' WLM IM ® Hole LWD/MWD Wire Mud Logging Notes Section Line TOC&Posi-Set#2=9374' 17'/2 _ gMWD,GR/RES Gas On Site Geologist liiiSS ® 12'/. Triple Combo 8'/2 Mudlog On Site Geologist Triple Combo,Form. Pressure Mudlog On Site Geologist TOC&Posi-Set#1=9510' w O EM Cementing Information Description Volume Density(ppg) Yield(ft3/sx) Notes Anil& (bbls) 7"Liner in 8 1/2"Hole Surface 1st stg 179/111 13.0/14.0 1.95/1.60 Bumped Plug MAX HOLE ANGLE=43.9°@ 7,689' MD Surface 2n°stg 285 13.0 1.95 Full Returns Intermediate 15'stg 228 14.0 1.95 Bumped Plug TD 10,290'MD/8,945'TVD Intermediate 2o1 stg 324 13.0 1.95 Bumped Plug PBTD 8,976'/7,996'TVD Production single stage 175.5 15.8 1.18 Packed off at L.H. 1A/-11 r\-a-a 1"111 AI A141 MS,. r\r\ A/,1"1.1A Chevron Schlumberger 1040 M-11 Final Field Surveys (Def Survey) Report Date: November 28,2010-1127 AM Survey I DLS Computation: Minimum Curvature/Lubinski Client: Chevron Vertical Section Azimuth: 35.000°(True North) Field: Trading Bay Unit Vertical Section Origin: 0.000 ft,0.000 ft Structure/Slot: Steelhead/leg Al slot 12 NO Reference Datum: Rotary Table Well: M-11 TVD Reference Elevation: 160.000 ft above Mean Sea Level Borehole: M-11 Seabed/Ground Elevation: 185.000 ft below Mean Sea Level UWI/API%: Unknown/50-733-20590-00 Magnetic Declination: 18.080° Survey Name: Actual Survey Total Field Strength: 55526.574 nT Survey Date: October 27,2010 Magnetic Dip Angle: 73.652' Tort/AHD/DOI/ERD Ratio: 158.033°/4343.009 ft 1 5.897/0.486 Declination Date: November 02,2010 Grid Coordinate System: NAD27 Alaska State Plane,Zone 04,US Feet Magnetic Declination Model: BGGM 2010 Location Lat/Long: N 60°49'54.48647",W 151°36 8.76214" North Reference: True North Location Grid N/E VIX: N 2499455.540 ftUS,E 214073.780 ftUS Grid Correction: 0.000° Grid Convergence Angle: -1.39932073° Total Corr Mag North.True North:18.080° Grid Scale Factor: 0.99999303 Local Coord Referenced To: Well Head MO ND Incl Azim True DLS VSEC NS EW Tray Cyl Azim- Tray Cyl Dist Comments (f) (n) (,) r) ("/10011) (R) (g) (R) North Ct-Ct Survey Tool 1°I (ft) Tle-In 0.00 0.00 0.00 0.00 N/A 0.00 0.00 0.00 N/A 0.00 LB_GYRO-MWD-Depth Orly Start BHA 02 264.71 284.71 0.08 221.49 0.03 -0.18 -0.14 -0.12 221.49 0.18 L8_GYRO-MWD-Depth Only 343.27 343.27 0.45 180.89 0.50 -0.49 -0.49 -0.16 198.53 0.51 LB_GYRO-MWD-Depth ONy 427.97 427.96 0.86 187.94 0.49 -1.33 -1.45 -0.26 190.03 1.47 SLB_GYRO-MWD 487.53 487.52 0.33 19.75 1.99 -1.57 -1.73 -0.26 188.55 1.75 SI9_GYRO-MWD 521.31 521.30 0.75 14.71 1.26 -1.27 -1.42 -0.17 186.84 1.44 SLB_GYRO-MWD 554.75 554.74 1.07 16.67 0.95 -0.76 -0.91 -0.03 181.61 0.91 SIB_GYRO-MWD 582.53 582.51 0.71 20.61 1.31 -0.35 -0.50 0.11 167.75 0.52 SLB_GYRO-MWD 610.94 610.92 0.45 12.50 0.97 -0.08 -0.23 0.20 139.80 0.30 SLB_GYRO-MWD 640.65 640.63 0.29 17.30 0.53 0.10 -0.05 0.24 100.85 025 SLB_GYRO-MWD 670.81 670.79 0.02 178.05 1.02 0.17 0.02 0.27 85.45 0.27 SLB GYRO-MWD 701.06 701.04 0.28 292.74 0.94 0.15 0.04 0.20 77.55 020 SIB_GYRO-MWD 731.73 731.71 0.50 305.73 0.78 0.14 0.15 0.02 45.62 0.22 SLB GYRO-MWD 763.71 763.69 0.70 290.00 0.80 0.09 0.30 -0.27 40.62 0.39 SIB_GYRO-MWD 795.91 795.88 1.08 271.80 1.45 -0.13 0.38 -0.76 49.59 0.58 SLB_GYRO-MWD 826.02 825.98 1.73 273.03 2.17 -0.53 0.41 -1.50 57.35 0.76 SLB_GYRO-MWD 855.39 855.33 2.55 263.48 3.04 -1.19 0.36 -2.59 66.82 0.91 SLB GYRO-MWD 890.63 890.52 3.56 267.80 2.94 -2.37 0.23 -4.48 77.31 1.03 SLB_GYRO-MWD 922.29 922.11 4.30 272.08 2.51 -3.61 0.23 -6.63 78.44 1.16 SLB GYRO-MWD 952.13 951.85 4.99 274.90 2.44 -4.87 0.38 -9.04 73.42 1.34 SLB_GYRO-MWD 985.53 985.11 5.53 276.75 1.69 -6.36 0.70 -12.09 66.10 1.72 SLB_GYRO-MWD 1080.42 1079.27 8.59 282.83 3.32 -11.20 2.81 -23.54 38.22 3.57 SLB_GYRO-MWD 1175.34 1172.78 1124 269.75 3.64 -19.22 4.34 -39.70 24.90 4.79 SLB_GYRO-MWD 127021 1265.35 14.00 273.53 3.04 -30.55 5.01 -60.41 12.50 5.13 SLB GYRO-MWD 1365.06 1356.85 16.52 265.70 3.42 -45.08 4.70 -85.32 357.31 4.71 SLB_GYRO-MWD End BHA 02 1390.11 1380.83 17.18 264.05 3.25 -49.76 4.05 -92.55 348.67 4.17 SLB_GYRO-MWD Start BHA 03 1456.12 1443.85 17.44 259.47 2.10 -63.21 123 -111.97 313.30 4.08 SLB_INC+TREND 1551.01 1534.44 17.27 250.60 2.79 -84.82 -6.04 -13924 285.44 6.15 SLB MWD+DMAG 1645.75 1624.84 17.66 239.30 3.60 -109.36 -18.06 -164.87 272.48 7.92 SLB MWD+DMAG 1740.54 1714.74 19.34 230.68 3.38 -137.58 -35.35 -189.38 260.17 9.64 SLB MWD+DMAG 1835.38 1803.61 21.58 223.41 3.57 -169.97 -57.98 -213.53 248.86 12.36 SLB_MWD-STD 193024 1891.37 23.07 21523 3.63 -205.82 -85.84 -23625 238.26 1525 SLB MWD-STD 2025.07 1978.14 24.59 207.76 3.56 -243.99 -118.49 -256.17 226.32 1724 SLB_MWD-STD 2119.76 2063.76 25.99 201.71 3.10 -283.74 -155.21 -273.02 212.43 18.30 SLB_MWD-STD 2213.67 2147.54 27.73 198.44 2.43 -324.71 -195.06 -287.55 198.17 18.97 SLB MWD-STD 2309.41 2231.53 2064 195.67 2.43 -368.41 -238.99 -300.99 184.62 19.61 SLBMWD- STD 2404.30 2313.10 31.81 193.89 2.47 -413.89 -285.87 -313.34 172.52 20.26 SLB_MWD-STD 249922 2393.50 32.40 193.63 0.84 -460.90 -334.86 -325.33 161.54 19.42 SLB_MWD-STD 2594.08 2473.59 32.43 193.09 0.30 -508.17 -384.33 -337.08 149.17 18.41 SLB MWD-STD 2688.98 2553.73 32.34 194.33 0.71 -555.52 -433.71 -349.13 136.46 18.05 SLB MWD-STD 2783.85 2634.01 32.05 194.23 0.31 -602.80 -482.69 -361.60 123.47 18.00 SLB_MWD-STD 2878.66 2714.82 31.00 194.08 1.11 -649.13 -530.76 -373.72 108.13 18.82 SLB_MWD-STD 2973.53 2796.98 29.00 191.35 2.55 -693.03 -577.02 -384.19 96.53 20.60 SLB_MWD-STD 3068.37 2880.58 27.35 189.21 2.04 -733.72 621.08 -392.21 90.23 22.79 SLB MWD-STD 3163.06 2965.13 26.15 189.55 128 -772.15 -663.13 -399.15 88.77 23.47 SLB_MWD-STD 3257.75 3050.60 24.82 188.68 1.46 -808.81 -703.36 405.62 91.91 21.94 SLB MWD-STD 3352.52 3137.09 23.45 186.84 1.65 -843.27 -741.75 -410.87 101.29 19.33 SLB_M1ND-STD 344728 3224.61 21.61 184.64 2.14 -874.95 -777.87 -414.52 118.91 17.42 SLB MWD-STD 3541.73 3313.09 19.36 180.69 2.79 -902.89 -810.86 -416.12 139.10 18.92 SLB W MD-STD 3636.52 3403.13 17.04 177.30 2.69 -926.86 -840.45 -415.65 153.47 23.45 SLB_MWD-STD 3731.42 3494.41 14.73 171.73 2.91 -946.65 -866.28 -413.26 161.64 29.75 SLB_MWD-STD 3826.22 3586.63 12.05 165.64 3.19 -961.88 -887.80 -409.07 165.84 36.67 SLB MWD-STD 3921.05 3679.72 9.88 160.06 2.55 -973.00 -905.04 403.84 168.78 43.83 SLB_MWD-STD 4015.92 377325 9.48 146.51 2.43 -980.54 -91921 -396.75 17028 52.53 SLB MWD-STD 4110.75 3866.83 9.27 131.77 2.53 -984.30 -930.81 -386.75 169.90 63.38 SLB_MWD-STD 4205.67 3960.48 9.58 118.34 2.34 -984.29 -939.65 -374.10 168.64 76.13 SLB MWD-STD 4300.43 4053.95 9.50 102.88 2.70 -980.43 -945.13 -359.53 16725 89.79 SLB W MD-STD 4395.24 4147.46 9.59 89.43 2.35 -972.89 -946.80 -344.01 165.48 100.83 SLB__MWD-STD 4490.04 4241.06 8.78 73.39 2.82 -962.62 -944.65 -329.18 163.87 108.10 SLB MW0-STD 4584.83 4334.76 8.67 56.44 2.71 -95029 -938.63 -316.28 162.84 111.18 SLB_MWD-STD End BHA 03 4674.78 4423.67 8.94 41.32 2.58 -937.03 -929.63 -306.02 162.34 110.41 SLB_MWD-STD Start BHA 04 4769.67 4517.31 9.69 35.49 127 -921.72 -917.59 -296.52 162.06 106.76 SLB_MWD-STD 4864.43 4610.48 11.32 35.66 1.72 -904.45 -903.55 -286.46 161.08 101.37 SLB MWDSTD 495864 4702.82 11.52 35.56 0.22 -885.80 -888.38 -275.61 159.25 95.21 SL8 MWDSTD 5053.44 4795.70 11.59 34.57 0.22 -866.81 -072.84 -264.70 157.09 88.86 SLB MWD-STD 514825 4888.58 11.56 34.82 0.06 -847.78 -857.19 -253.87 154.62 82.52 SLB_MWDSTD 5233.10 4971.72 11.45 34.37 0.17 -830.86 -843.26 -244.26 152.16 77.03 SLB_MIND-STD 5337.90 5074.42 11.58 33.47 021 -809.95 -825.90 -232.59 148.66 7024 SLB MWD-STD 5432.90 5167.49 11.55 33.05 0.09 -790.91 -809.98 -222.14 144.86 64.13 SLB_MNNSTD 5527.80 5260.35 1223 33.35 0.72 -771.37 -793.62 -211.43 139.79 58.19 SLB_M5SD-STD 5622.78 5352.73 14.62 31.26 2.57 -749.35 -774.97 -199.68 132.09 52.03 SL6_MWD-STD 5717.62 5443.94 17.14 30.66 2.66 -723.46 -752.71 -186.34 122.96 45.75 SLB MWD-STD 5812.58 5534.17 19.18 33.30 2.31 693.92 -727.63 -170.64 112.44 40.54 SLB_MWD-STD 5907.03 5622.80 2124 3624 2.44 -661.30 -700.86 -152.00 101.80 37.35 SLB MWDSTD 6002.42 5710.98 23.59 3827 2.59 -624.96 671.94 -129.96 91.92 35.86 SLB MWD-STD 6097.32 5797.26 25.62 40.96 2.45 -585.59 -641.53 -104.75 84.37 35.58 SLB_MWD-STD 6192.10 5881.99 27.63 43.65 2.47 -543.48 -610.15 -76.14 80.60 35.93 SL8 MWDSTD 6286.92 5965.17 29.73 43.13 2.23 -498.46 577.08 -44.89 79.30 35.82 SLB_MWD-STD 6381.83 6046.56 32.18 43.80 2.60 -450.18 -541.66 -11.30 79.22 34.99 SLB MWD-STD 6466.19 6117.22 34.04 44.11 2.21 -404.66 -508.49 20.69 79.72 33.49 SLB_MWD+DMAG End BHA 04 6567.35 6199.98 36.16 43.89 2.10 -347.21 -466.64 61.09 80.25 29.98 SLB MWD+DMAG Start BHA 05 6645.95 6262.98 3728 43.93 1.43 -300.79 -432.79 93.68 80.89 25.64 SLB_MWD-STD 6740.80 6338.58 37.01 42.86 0.74 -244.13 -391.17 133.03 80.80 19.60 SLB_MWD-STD 6835.64 6414.31 37.03 41.62 0.79 -187.48 -348.90 171.12 78.17 13.79 SLB_MWD-STD 6930.49 6489.94 3721 39.87 1.13 -130.53 -305.53 208.77 74.64 11.47 SLB MWD-STD MD TVD Incl Azim True DLS VSEC NS EW Tray Cyl Azim- Tray Cyt Dist Comments (ft) (ft) fl 1°) (*MOM (ft) (ft) (ft) North Ct-Ct Survey Tool r1 Ift1 7025.40 6565.58 37.12 37.11 1.76 -73.32 -260.67 244.45 75.06 10.89 SLB_MWD-STD 7120.24 6640.34 38.85 33.25 3.10 -14.97 -212.96 278.03 82.44 9.89 SLB_MWD-STD 7215.09 6713.66 39.90 29.88 2.51 45.07 -161.69 309.50 94.02 9.02 SLB_M0617-STD 7309.81 6785.68 41.12 27.75 1.94 106.24 -107.78 339.14 114.31 9.30 SLB_MWD-STD 7404.71 6856.57 42.21 27.59 1.15 168.81 -51.91 368.44 130.53 11.76 SL9_MWD-STD 7499.60 6926.28 43.24 28.13 1.15 232.69 5.01 398.52 134.05 14.49 SLB W MD-STD 7594.52 6995.10 43.82 26.70 1.20 297.49 63.04 428.62 132.63 16.36 SLB__MWD-STD 7689.39 7063.51 43.89 25.15 1.14 362.39 122.15 457.35 131.24 16.46 SLB_MWD-STD 7784.24 7131.92 43.80 24.27 0.65 427.03 181.84 484.82 131.23 15.23 SLB_MWD-STD 7879.06 7200.44 43.65 23.72 0.43 491.37 241.72 511.47 133.03 13.28 SLB_MWD-0TD End 8HA05 7972.61 7268.11 4369 23.07 0.48 554.64 301.00 537.12 137.16 10.78 SLB_MWD-STD Start BHA 06 8068.65 7337.64 43.54 24.56 1.08 619.63 361.61 563.86 142.93 8.78 SLB_MWD-STD 8163.37 7406.37 43.42 25.41 0.63 683.81 420.68 591.39 147.39 8.16 SLB_MWD-STD 8258.24 7475.19 43.57 25.14 0.25 748.17 479.73 619.27 150.93 7.84 SLB_MWD-STD 8352.97 7543.87 43.51 26.38 0.91 812.58 538.50 647.63 151.84 7.96 SLB_MWD-STD 8447.78 7612.68 43.42 26.37 0.10 877.06 596.93 676.60 150.63 8.72 SLB_ W MWD-STD 8542.64 7681.51 43.55 26.57 0.20 941.61 655.36 705.70 149.08 9.55 SLBMD-STD 8637.44 7750.32 43.37 26.73 0.22 1006.13 71364 734.94 147.39 10.58 SLB__MWDSTD 8732.29 781924 43.43 26.60 0.11 107061 771.88 764.19 146.38 1169 SLB_MWD-STD 8827.22 7888.17 43.44 26.41 0.14 1135.16 830.29 793.31 145.71 1261 SLB_MWDSTD 8922.10 7957.12 43.34 27.18 0.57 1199.67 888.46 822.70 144.75 13.86 SLB_MWD-STD 9016.99 8026.10 43.41 26.60 0.43 1264.18 946.59 852.17 143.83 1522 SLB_MW0-0TD 9111.89 8095.02 43.45 26.47 0.10 1328.71 1004.96 881.31 143.43 16.18 SLB MWD-STD 9206.61 8163.55 43.86 26.07 0.52 1393.34 1063.59 91025 142.41 16.71 SLBMWD-STD 9301.36 8231.78 44.01 24.92 0.86 1458.18 1122.93 938.55 141.32 16.24 SLB__MWD-0TD 9396.22 8300.05 43.93 24.37 0.41 1522.97 1182.79 966.01 141.54 14.86 SLB_MWD-STD 9491.00 8368.33 43.89 24.50 0.11 1587.59 1242.64 99321 142.64 13.32 SLB_MWD-STD 9585.74 8436.65 43.81 24.40 0.12 1652.11 1302.38 1020.37 144.42 11.86 SLB_M18J0-STD 9680.52 8505.14 43.65 24.82 0.35 1716.55 1361.95 1047.66 147.09 10.67 SLB_MWD-STD 9775.50 8573.73 43.88 2320 1.20 1781.04 1421.96 1074.39 152.73 8.92 SLB_MWD-STD 9870.35 8642.12 43.85 23.57 0.27 1845.43 148229 1100.48 164.43 6.70 SLB_MWD-STD 9965.12 8710.37 44.00 2361 0.16 1909.88 1542.54 1126.79 182.66 4.98 SLB_MWD-STD 10060.02 8778.72 43.85 22.99 0.48 1974.34 1603.01 1152.83 217.31 4.24 SLB_MWD-STD 10154.81 8847.23 43.59 2423 0.94 2038.56 1663.03 1179.07 244.77 5.23 SLB_MWD-STD 10224.64 8897.74 43.74 24.30 0.22 2085.93 1706.98 1198.88 254.05 6.07 SLB_MWD-STD Projection to TD 10290.00 8944.97 43.74 24.30 0.01 2130.33 1748.17 1217.47 260.99 6.91 SLB BLIND Survey Type: Def Survey M-11 Mud Weight vs. Depth (MD &TVD) woo 2000 3000 4000 —4—Mud Weight Vs.MD —M—Mud Weight Vs.ND 5000 6000 ■ 7000 8000 8.2 8.4 8.6 8.8 9 9.2 9.4 9.6 I co co O �O Z Z rn oco o o u 1 C N N U, csi in .rt, U) c7I N m P '' co c P. (7, r) NZ r r a) r _,:- ca-a) N a) I-- M ri 1— di � o wxz a co u N- co M ,,,z- r) d O1 c b eey C4 to rn Q NNUJ Cn o CD F-- �1 r II X 11 rn ca >- -J N —1 o ti 1.... o csi Ln en p efi L� a? Li- < .� I Z `,Y U) ZLL 0- 0 U. p Q EL 0 i Q r NO M 0 0 ZZ 0 a)0 o 0co 0 co Page 1 of 1 Aubert, Winton G (DOA) From: Ross, David A. [Swift Oil and Gas][rossda@chevron.com] li Sent: Monday,January 10,2011 8:46 AM 2 Ip - (4 5 To: Aubert,Winton G(DOA) Cc: Kanyer,Christopher V; Bonnett, Nigel(Nigel.Bonnett);Tyler, Steve L Subject: M-11 Completion Status Mr.Auber, This message is to inform you about the completion status of Steelhead Well M-11. II, The secondary target sand F-16(9420'-9440'WLM) has also been identified as a water producer with no commercial gas and as a result we have isolated it with second posi-set plug capped with cement and subsequently perforated the F-15B sand (9270'-9290'WLM)with e-line guns. We are currently gas lifting the well to unload completion fluid and will be flow testing the F-15B throughout the day. If the F-15B does not produce,we will be making a second tubing tail cut and isolating the fish and the F- 15B sand with another posi-set plug capped with cement. The final interval that will be perforated prior to the need for a major workover will be the F-11 sand (8946'-8977'WLM)which has the highest POS. Should you require any additional information don't hesitate to contact me at your earliest convenience. David Ross •. • Alaska wellbore Maintenance Team Chevron North America Exploration&Production(MCA) Office: (907)263-7696 Cell: (907)903-9555 Fax: (866)244-1439 Email: rossda@chevron.com Page 1 of 1 Aubert, Winton G (DOA) From: Ross, David A. [Swift Oil and Gas] [rossda©chevron.com] Sent: Thursday, December 30,2010 3:30 PM To: Aubert,Winton G (DOA) Cc: Nienhaus, Doug R; Bonnett, Nigel(Nigel.Bonnett); Flynn,Tim [ASRC] Subject: M-11 Completion Status 110- ICS Mr.Auber, This message is to inform you about the completion status of Steelhead Well M-11. After TCP perforating,the initial target sand G-05 (9830'-9868'WLM)has been identified as a water producer and as a result we are planning to;cut the tubing tail. isolate the G-05 and fish with a posiset plug capped with cement and subsequently perforate the F-16 sand(9418'-9474'WLM)with e-line guns. This will be a rig-less operation as the production tree has already been installed. Should you require any additional information don't hesitate to contact me at your earliest convenience. David Ross 4- + Alaska Wellbore Maintenance Team Chevron North America Exploration&Production(MCA) Office: (907)263-7696 Cell: (907)903-9555 Fax: (866)244-1439 Email: rossdanchevron.com Chevron Fra...:isco Castro Chevron North Am ..ca Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 11110 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE December 20, 2010 To: AOGCC Shartzer, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL INTERVAL WELL LOG TYPE LOG DATE ,LOGGED 1NE CD TBU M-11 USIT LOG 12/06/2010 300-10168 X X qq/ RECEIVED 0 � [EC 7 2010 l 0 f)l-�f��, Alaska Oil,3 Gas Cons. Commission Mchoc q Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By:/ M1 Date: Aft r 'Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE December 21, 2010 To: AOGCC Shartzer, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL WELL LOG TYPE LOG DATE INTERVAL B- CD LOGGED LINE TBU M-11 DCS ANALYSIS REPORT 11/25/2010 X X /, /CD Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received,67-y• y Mq �riji ��Wb j��99��}},, ..'® .. .ncrarace Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcastro@chevron.com DATE December 16, 2010 To: AOGCC Shartzer, Christine R 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL INTERVAL B WELL LOG TYPE LOG DATELOGGED LINE CD TBU M-11 VISION SERVIECE&ECOSCOPE RECORDED MODE 11/3-29/2010 377-10263 X X LOG MD TBU M-11 VISION SERVIECE&ECOSCOPE RECORDED MODE 11/3-29/2010 377-10263 X X LOG SSTVD TBU M-11 FINAL DIRECTIONAL SURVEY 11/3-29/2010 0-10290 X X TBU M-11 FINAL WELL REPORT-MUDLOG 11/3-28/2010 470-10290 X X al 415 a® V 7 i Menai-Age s,0a Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: Page 1of1 A Regg, James B (DOA) From: Regg, James B (DOA) iZ191(0�� Sent: Tuesday, December 07, 2010 10:45 AM To: 'Ross, David A. [Swift Oil and Gas]'; DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Cc: Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett); Hauck, Shane R; Menapace, Michael Sam Subject: RE: M-11 Casing / Liner Lap Test Thank you for the test chart for TBU M-11 (PTD 210-145). Your request to defer the BOPE test is approved based on a successful casing/liner lap test to 3000psi and the sequence of the remaining operations you describe below. Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Ross, David A. [Swift Oil and Gas] [mailto:rossda@chevron.com] Sent: Tuesday, December 07, 2010 9:09 AM To: Regg, James B (DOA) Cc: Nienhaus, Doug R; Bonnett, Nigel (Nigel.Bonnett); Hauck, Shane R; Menapace, Michael Sam Subject: M-11 Casing/ Liner Lap Test Mr. Regg, As requested attached please find a picture of the Martin Decker chart which shows the successful 3000 psi casing/liner lap test on the M-11 well we performed on 12-5-10. We began running the lower completion at 9:30 am on 12-6-10 and we are currently pulling out of the hole with the DP and packer setting tool. We plan to start running the upper 31/2" completion around mid afternoon today. It is estimated to take 18 hours to land the completion, after which we will N/D the BOPE and N/U the production tree. The well will be perforated after the tree has been tested and the flowlines have been installed. Please advise if it will be acceptable to forego the scheduled BOPE test based on the current status of the well. 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' - :•,;',3",.. .!:-,"7'-‘,•.;!:';'•,,, -,?," ,*',:: ,.,,.,_..,,;.,,,• •: :''(..--**!-!..['.7,- ;4e ''.*:,..',•., i:•!-Jt.k..'-,,,..: :';'3,,...**:.,2,.;',',..".?;,...„,':', -7,i.;;„",.*7.'..?**:,,,,*••4..'.2i,'.,',•,..,77.7-,`,.';---...:,-,1,..[,."2-_,-;',',142,'!!:14,C•*;!* -4....."...; .6-.,--,,-,...--,- /_-,,,:i.-,-:,.•-•.,-.J.4,..1-;_•-,...,t-,,,f.,,-•17--7--..-r.e:',--••---„,--- ---- 14' 7• 1 • '2; v• ) - ' • r .. ...., ,,,,, „,, .,. ,,,, ,,,,.. , ., r ' ' ' ' ,.,. 3.... .... . ,... _ ....., . . . . 3 ' 1 ' . ..- . ..., • .. . . -: -.., .. ....... ,,. . _ SLAITE CHF ALMA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Grayling Gas Sands, TBU M-11 Union Oil Company of California Permit No: 210-145 Surface Location: 1048' FNL, 457' FWL, SEC. 33, T9N, R13W, SSM Bottomhole Location: 707' FSL, 1687' FWL, SEC. 28, T9N, R13W, SSM Dear Mr. Brandenburg: 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 an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Chair !-4 DATED this 7-day of October, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA io/a*jieEo ALA, A OIL AND GAS CONSERVATION COMk...,SION SEP 2 9 2010 PERMIT TO DRILL Atnca0186seGets.CINIIWOD 20 AAC 25.005 1 a.Type of Work: lb.Current Well Class: Exploratory ❑ Development Oil ❑ 1 c.Specify if well is proposehrthaPege Drill Q Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas Q Coalbed Methane ❑ Gas Hydrates ❑ Re-entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well ❑ 11.Well Name and Number: Union Oil Company of California Bond No. 086S103515406BCM Tradng Bay Unit M-11 3.Address: 6.Proposed Depth: 12.Field/Pool(s): PO Box 196247,Anchorage,AK 99519 MD: 10290 • TVD: 8950 McArthur River Field 4a. Location of Well(Governmental Section): 7.PpMesignation: Grayling Gas Sands Surface: 1048 FNL,457'FWL,Sec 33,T9N, R13W,SSM AD_L17AOL 18730 ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud D- 1071'FNL,301'FWL,Sec 33,T9N,R13W,SSM NA 16/ 1 2010 Total Depth: 9.Acres in Property: 14.Distance to Nea 707'FSL, 1687'FWL,Sec 28,T9N,R13W,SSM 5116,3840 Property: >6000' 4b.Location of Well(State Base Plane Coordinates): 10.KB Elevation 15.Distance to Nearest Well Surface: x-214073 • y- 2499455 • Zoi 4 - (Height above GL): 160 AMSL feet Within Pool: 1900' (M-32) 16. Deviated wells: Kickoff depth: 600 feet • 17.Maximum Anticipated Pressures in psig(see 20 5.035) Maximum Hole Angle: 43 degrees Downhole: 3893 • Surface: 998,.' 18.Casing Program: Specifications Top - Setting Depth - Bottom ement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 28-32 1/2-1"WT X-56 Weld 0 S}irface Surace 470 470 Driven 17 1/2" 13 3/8" 68.L-80 BTC 420 urface Surface 1420 1410 3190 ft3 in 2 stages V 12 1/4" 9 5/8" 47 L-80 BTC-M 6520 Surface Surface 6600 6247 3550 ft3 in 2 stages ----- 8 1/2" 7" 26 L-80 DWCSR 3810 6400 8950 10290 8950 1059 ft3 in 1 stage 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 ND Conductor/Structural 401.00 28-32 Driven 470 470 - Surface - Intermediate Production Liner Perforation Depth MD(ft): NA Perforation Depth ND(ft): NA 20. Attachments: Filing Fee ❑ BOP Sketch ❑✓ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Property Plat Q Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program❑✓ 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date _ 9/20/2009 22. I hereby certify that the foregoing is true and correct. Contact Tim Flynn 907-263-7824 Printed Name pp Timothy Brandenburg Title Drilling Manager Signature 1! ...) . ---* Phone Date 9 . 2.. . Lc.t Commission Use Only Permit to Drill „, ��- API Number: �, ..� Permit Appr val See cover letter for other Number. Z�Z` 50 �� � -' ����' Date: ) ��q�AD requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,ga hydrates,or gas contained in shales:g Other:—' y� 7 Samples req'd: Yes❑ No[ Mud log req'd: Yes No[✓� l t5•� A.w 4r 730 tc loco � . e 5� rawer H25 measures: Yes[.1 No❑ Directional svy req'd: Yes No[i] T 13 l'E tv 3000 er,Z, . Pur fo Zo L. ZS. Ck1(1), c&;Je✓f'erus�f' 'tr( V4✓6kKc .. is s fhoYed• ?K r iaucE t-o Zo 4kc zs. o 3 s COLO, ea tw K-ct-t. 1.o PE d c a,t p roV><d. /6'/ ?://9 © � / D1:44*---" .....7" APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-4 1 Revised 12/2005 11P I ( I n i A I Submit in Duplicate__..i/•h-, Chevron Timothy C Brandenburg Union Oil Company of California 1%0 Drilling Manager P.O. Box 196427 Anchorage,AK 99519-6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt@chevron.com 09/29/10 WINE D Commissioner Alaska Oil &Gas Conservation Commission SEP pLU`IJ 333 W. 7th Avenue Anchorage, Alaska 99501 Mill d les tars.Cetiftlt yion Re: Steelhead Platform,Trading Bay Unit M-11 A9tCfterege Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Trading Bay Unit M-11 well from the Steelhead Platform. Drilling operations are expected to commence approximately October 20, 2010 depending on the progress of other ongoing projects. Per Conservation Order 228, Trading Bay Unit requires 10 acre spacing. There are no wells producing or capable of production from the target strata of TBU within 745' of the planned wellpath of TBU M-11. Therefore, a spacing exemption is not required to drill or produce TBU M-11. In accordance with 20 AAC 25.005(c)(4)(A-C)... (A) MASP calculations are attached for review. (B) The Grayling Gas Sands are potentially gas bearing throughout the section. Potential target reservoirs and their predicted pore pressures are indicated in the attached M-11 Well Design Summary. (C) Due to ongoing production operations in this field, sub-normally pressured sands occur in multiple places. Lost circulation and differential sticking are potential problems. Conventional solutions such as LCM and good drilling practice are intended to ameliorate the problems. An exception to 20 AAC 25.035(c)(1)(B) is requested. The diverter system at Steelhead includes two 16" diameter diverter lines. The surface hole section of M-11 is planned to be drilled with a 17'/2' bit. Union Oil Company of California /A Chevron Company Pape 1 of 2 An exception to 20 AAC 25.035(e)(3) is requested. The BOP stack for Steelhead includes 20 %" 3M ram preventers and a 21 W 2M annular preventer. The MASP for the subject well, when calculated in the most pessimistic manner, exceeds the rated working pressure of the annular preventer. The annular preventer will not be used in a secondary well control event in excess of its rated working pressure. Union Oil Company also requests that the test pressure for the annular be established at 1000 psi. The annular preventer has been previously tested to 2000 psi. Repeated testing to 2000 psi will degrade the annular element. Pursuant to 20 AAC 25.005(c)(14)... Qualified drilling waste will be discharged in accordance with NPDES permit AKG-31-5000 • which became effective 7/2/2007 and expires 7/2/2012. At this time, Union Oil Company does � not intend to apply for annular disposal approval. The remaining requirements of 20 AAC 25.005 are attached for review or currently on file with the Commission. If you have any questions, please don't hesitate to contact myself or Tim Flynn at 907-263-7824. Sincerely, ,/O Timothy C. Brandenburg Drilling Manager Attachments: Form 10-401 in Duplicate M-11 Cementing Calculations M-11 Well Design SummaryM-11 CasingDesign 9 9 M-11 Summary Drilling Procedure M-11 MASP Calculations M-11 Summary Mud Program M-11 FIT/LOT Procedure M-11 Planned Well Sketch M-11 Spider Plots - Schematic M 11 Planned Well Trajectory M 11 Combo BOP/Diverter M-11 Drilling Hazards Notice M-11 Choke Manifold Schematic M-11 Plat Cc: File Union Oil Company of California/A Chevron Company Page 2 of 2 Davies, Stephen F (DOA) From: Flynn, Tim [ASRC] [Tim.Flynn@chevron.com] Sent: Thursday, September 30, 2010 4:10 PM To: Davies, Stephen F (DOA) Cc: Bonnett, Nigel (Nigel.Bonnett); VOORHEES, BRENT J Subject: M-11 Logging program Steve See below the logging program for well M-11 that will be drilled off of Steelhead platform: All logging data will be acquired by MWD while drilling. 17.5" hole section Gamma Ray Resistivity(Used to determine bottom of conductor) Gas monitoring w/Canrig Mudlogging 12.25"hole section Gamma Ray Resistivity Neutron Density Formation Pressure (Various intervals through the Grayling Gas Sands) Mud Logging 8.5"x 9.0"hole section Gamma Ray Resistivity Neutron Density Formation Pressure (Various intervals through the Grayling Gas Sands) Mud Logging Cased hole logging USIT from 700'MD*to 10,000'MD *The top depth will be based on tool accuracy Tim Flynn Operations Drilling Engineer Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage,AK 99503 907-263-7824 phone 907-317-5504 cell 1 Chevron %.1 Steelhead Platform Well M-11 Well Design Summary M-11 Well Design Summary Steelhead M-11 is a development well drilled in a NNE direction from slot Al-12. The well penetrates multiple primary and secondary Grayling Gas Sand targets from the SZl 1 to TD below Base GGS/Coal39 and in upper G oil sands. M-11 is designed as an "S" shaped, well reachin 43.degrees inclination in the tangent section and reaching a total depth 10307' MD, 8960' TVD. Basic Well Information Platform: Steelhead Well Name: M-1 1 Estimated Spud Date: 10/20/2010 Field: McArthur River Productive Horizon: Grayling Gas Sands • PTD: TBD Total Depth: 10290' MD, 8950' TVD Slot: Slot A1-12, SW Leg Surface Location: 1048' FNL, 457' FWL, Sec 33, T9N, R13W, S X=214073.78, Y=2499455.54, NAD27, ASP, Zone 4 Planned BHL: 707' FSL, 1687' FEL, Sec 28, T9N, R13W, SSM Original KB Elevation: 160' AMSL KB to THF: TBD Casing and Tubing Program Hole Tube Weight Length Top Btm Size (in) O.D. (lbs / ft) Grade Conn (ft) MD/TVD MD/TVD (in) (ft) (ft) Driven 28-32 X-56 Weld 390 BF 470 17 1/2 13 3/8 68 L-80 BTC 1340 BF 1420/1410 12 1/4 9 5/8 47 L-80 BTC-M 6520 BF 6600/6247 81/2 7 26 L-80 DWCSR 3909 6400/6087 10290/8950 TBG 31/2 9.2 L-80 TC-II TBD THF ; TBD 9/28/2010 Chevron Steelhead Platform Well M-11 Well Design Summary Well Control Summary Hole Section Equipment Test Pressure (psi) 17 '/2" 21 1/4 2M Diverter c/w 2 ea 16" 600 psi Diverter Function Valves* 21 1/4 2M Annular, 20 3/4 3M Double Gate, / 12 1/4" 20 3/4 3M Mud Cross, 20 3/4 3M Single Gate 250/3000 3 1/8 5M Choke Manifold* (Annular 1000 psi) 21 '/4 2M Annular, 20 3/4 3M Double Gate, i 8 1/2" 20 3/ 3M Mud Cross, 20 3/4 3M Single Gate 250/3000 3 1/8 5M Choke Manifold* (Annular 1000 psi) *Schematics of the well control equipment are attached for reference Anti-Collision Evaluation Summary There are two close approach wells in the surface section of M-11 . Collision risk will be mitigated procedurally by monitoring annular pressures of adjacent wellbores and placing an observer in the wellhead room to listen for indications of a collision. A Gyro MWD tool will be used to accurately survey the wellbore in the surface hole while drilling. Close Approach M-11 Path Ellipse Separation Diverging From Well (MD ft) (ft (ft) M-13 513-557 ,�4::3 438 M-20 689 ( 1 .46 689 G-23 6474 88.78 6474 9/28/2010 PaaP 7 of d Chevron %. Steelhead Platform Well M-11 %. Well Design Summary Formation Integrity Testing Test Point, 20' Projected Projected Test Projected Below... Depth Test Type (EMW ppg) j Casing Test / (TVD) (PSI) 13 3/8" Csg Shoe 1410 FIT 13.0 1500 _ 9 5/8" Shoe 6247 FIT 13.0 3000 7" liner 3000 Mud Program Summary Section Depth Mud Type Density Viscosity PV YP API FL (MD ft) (ppg) (sec) 17 1/2" Surf. 0-1420 Pre-Hyd Gel 9.0-9.3 60-85 10-28 25-35 <12 12 1/4" Interm. 1420-6600 KCL/GEM/Pmr 9.1-9. . 40-53 6-15 13-20 <_6 8 1/2" Prod. 6600-10290 KCL/GEM/Pmr 9.2 40-53 6-15 13-20 <_6 ti Cementing Summary See Attachments Formation Markers Zone Top Depth Ft Depth Ft Pore Pressure EMW Requirement Measured RKB TVDsubsea psia (ppg RKB) Tyonek SZ11 1529 -1356 404 5.73 Tyonek SZ12 1644 -1465 240 3.15 Tyonek SZ17 2113 -1906 254 2.56 Tyonek A2 2867 -2543 389 2.94 Tyonek A3 3024 -2677 633 4:5 Tyonek B5 3792 -3397 314 Tyonek B8 4033 -3637 581 3.07 Tyonek Cl 4145 -3748 246 1.26 Tyonek D2 4823 -4420 342 1.48 Tyonek D3B 4994 -4590 299 1.25 Tyonek D6ST 5301 -4893 425 1.67 Tyonek D14 6151 -5711 2376 8.0 9/28/2010 Chevron Steelhead Platform Well M-11 Well Design Summary Tyonek D16C 6323 -5862 273 .89 Tyonek F7 8514 -7505 3125 7.84 TyonekFl5B 9213 -8011 3342 7.86 Tyonek F16 9385 -8136 1292 2.99 Tyonek G05 9806 -8440 1321 2.95 Tyonek GI 9923 -8524 3708 8. Tyonek GI 10290 -8790 3823 8.26 9/28/2010 Chevron 110 Steelhead Platform Well M-11 Basic Drilling Procedure M-11 Basic Drilling Procedure 1 . RU Steelhead rig over slot Al-12. 2. Install A section wellhead and test. 3. Install 21 1/4 2M /20 3/4 3M combo diverter/BOP stack and dual 16" diverter lines. Function test diverter per AOGCC requirements. 4. MU 17 1/2" bit and clean out conductor to 480'. 5. MU 17 1/2" directional BHA and drill to 1420'MD' taking gyro surveys as necessary. (Set shoe in sand 200' above productive gas zone) 6. MU jet wash tool and wash out conductor to 470'. 7. Run and cement 13 3/8" casing to surface in 2 stages utilizing an ECP stage i collar. 8. Install 13 5/8 multi bowl wellhead system. NU BOP stack. •ll blind flanges on diverter outlets. Install 9 5/8 rams. Test stack to 250/ 000. 9. MU 121/4" drill out BHA and drill out stage tool. Test c• ' g to 1500 psi. 10. Drill out shoe track and perform FIT to 13.0 ppg EMW. 11 . Directionally drill to 6600'MD. (200' below D-16) - Drill w/ RSS + mill tooth bit, r then TD with RSS + PDC bit. 12. Run and cement 9 5/8 casing to ML in 2 stages. 13. Redress BOP's w/ 7" rams and test 250/300prpsi. Test 9 5/8" casing to 3000 psi i 14. MU 8 1/2" x 9" directional BHA and drill Perform FIT to 12.8 ppg EMW. 15. Directionally drill to section TD at 10,290'MD. 16. Pull wiper trip. 17. Run 7" Liner, hanger, and liner top packer. Set liner hanger and cement. Set packer. 18. Redress BOP's and test 250 3001: Test 7" liner to 3000 psi. 19. PU clean out string and mei. = •it and scraper runs to PBTD. 20. Displace to completion fluid. (FIW then to 6% KCL w/ surfactant) 21 . RU TCP guns and perforate productive intervals. 22. Run 3 1/2 tubing w/ TCP guns. Space out and land tubing. Test void. 23. Install BPV and ND BOP. 24. NU tree and test to 5000 psi, RU gas/production lines 25. Gas lift well to achieve desired under-balance 26. Drop bar to perforate well, produce well 27. RDMO Steelhead rig. 9/23/2010 T,.�- 1 __.C1 Halliburton BAROID Chevron Mud Program M-11 Fluid Properties Surface Hole Recommendations (17-1/2" hole, 13-3/8" casing to 1,420' MD) System Type: Pre-hydrated Gel Spud Mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 470'-1420' 9.0-9.3 60-85 10-28 25-35 <8 8.5-9.0 Intermediate Hole Section Recommendations (12-1/4" hole, 9-5/8" casing to 6,600' MD) System Type: 2% KCI, Clayseal, GEM Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 1357'-6600' 9.1-9.3 40-53 6- 15 13-20 <6 8.5-9.5 • Additional mud weight may be required for effective coal or shale stabilization. Production Hole Section Recommendations (8-1/2" hole, 7" liner to 10,250' MD) System Type: 2% KCI, Clayseal, GEM Properties: Depths _ Den Viscosity Plastic Viscosity Yield Point API FL pH 6600'-10250' 9. -9. 40-53 6- 15 13-20 <5 8.5-9.5 Completion (3-1/2" Tubing to 9.800' MD) System Type: 6% KCI Brine Properties: Density - 8.5 ppg, Chlorides — 15,000 ppm M-11 1 9/9/10 0 C E mnt.8.N ONNpmpN tp00np '4. ?-!q NOmtnp wN b npNSd. vS4Y N z110rym N FAH aD I�nM MAI �M �O h�b n^�t�� ON�mN V dtn'IN 01 W e avaa OOOMM nSogf oqi tql ii pmj MMM M m�mq �rjMSn n bM bN a N N N N N 7-7,74;:2 N N N N N N N N N N N N N N N N N N N N N N N N N N N m a v pp N C N I,1,% N mmm NNIS NNT gA:=2m NSMmm Z2 r.N V wq az--2.,1. <;S t X fl, f;-;, ft; oNOi admin NMNON Tnb db 'N^N O N N N W A W pd1 W W W W W W ONq. 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( � ƒ©§§§ ] a 42 " a \\ 0 /\ 0 ,m A Chevron Schlumberger WELL M-11 (P10) FIELD575047050 ELD Trading Bay Unit Steelhead Magnetic PawnNan Surface Lmabon 1111327 Alaska Slale Plane.Zane 01,US Feet Miscellaneous Model: BOOM 2010 Dip'. 73552• Dale: November 10,2010 Lat'. N 60.951.188 NMbi, 21991555188/5 GrlB Cam'.-139932073• 58/ leg Al WO 12 WO Ref Rolary Table(1608 above Mean See Level) Map Dec: 18.073• FS: 55528 1n Lon'. W 15136 8762 Eatl9w 211073 74 nus Scale Facl'.060500303 Plan: M-11(P10) 5.9y Dale'. -1200 0 1200 2400 3600 0 RTE_ • 0 KOP Bld 1.5/100 Bld 2.5/100 1200 PanA.BW • 1200 cm 3/100 13-3/8"Csg _.._..-.._..-..-..-.._..F.._.._.._.._.._.._. ._.._..-.._._.._.._..-..-..-..-.._.._._.._.._.._.._.._.._.._..1.. 2400 _ - _.. .. _.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._..:. 2400 :.._..:::::::::::::::::)paisi :::::. •! .._ :.._..:.._.._..:.._.._:;_.._.._.._.._.._.._.._._;:_.._.._.._.._.._.._.._::�:: §t ler -..-..-..-..-..-.._"-"r-.._.. :582-.._.._.._.�.._.._.._.._.._.._.._.._.�_.._.._.._..-.._.._.._.._j._.._..-..-..-..-..-..-..�.. -..-.._.._.._.._.._.._..*.._...d§Y_.._.._.._.._...._.._.._.._.._.._.._.._.;_.._.._.._.._.._.._.._.._;._.._..-.._.._.._.._.._..�.. 3600 =::_::_::_::_::_::_::_ _ o-••_.._.._.._.._.._.._.._.;_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.. .. 3600 •:85_2. .. .. .. .. .• int._.._.._.._.._.. - o _.._.._.._.._.._.._.._. p2_.._.._.._.._.�.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._. i.. End Cry c CO 0 Cry 8/100 9-5/8'Csg End Cry 6000 ...,....:,.:..:.:.,..,.::4::•.,:•.:�.::•,::••,�: • ,•:.1.:�.:��:..•::.::•.::,.:,•.:.�:•.,•:.•::.•::.•.�.:�.::•.:�.:��r:�:�,•::.:�.:�.:��::•i::•.:�.r.•: 6000 am 3/100 End Cm 7200 7200 _.._.._.._.._.._.._ ►.._.._.._.._.._.._.._.._ _.._.._.._.._.._.._.._ X52.-.._.._.._.._.._.._._.._.._.._.._.._.._.._..�.. ••-•t•:_..:::_T=: 8400 -.._.._.._.._.._.._.._ :.._.._.._.._.._.._.._.._.:.._.._.._.._.._.._.._.._:_.._;; ._. .._.._:._.._.._.._.._.._.._.._.._.. 8400 _.._.._.._.._.._.._.._ }.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._y_..-.._.._.._.1-. ._.._j._.._.._.._.._.._.._..—..K.. -11 jp10) -1200 0 1200 2400 3600 Vertical Section(ft)Azim=35.81°,Scale=1(in):1200(ft) Origin=0 NI-S,0 E/-V Chevron Schlumberger WELL FIELD STRUCTURE M-11 (P10) Trading Bay Unit Steelhead Magnetic Pannelers Surf.Location NAD21 AYeba Slate Plane.Zone Oa,US F. MNa114..4 Model: BOOM 2010 Dip'. 13.652' Date: November 10.2010 Lot: R 609959.998 Northing'. 249995854 SUS Grid Co.,.'.-1.39932073' SW: leg A141312 11/13 Red: Rol.Tebb(16011 aboveMan S.Level) Map Dec: 15073' FS'. 55526401 Lon: W 151 36 8782 E.44rp: 214073.78000 Sale Facd'.099999303 PMn: M-11(P10) Srv7 Dote: -400 0 400 800 1200 2000 2000 TD -11(P10) 1600 1600 Tar 1200 a 1200 A • 800 800 A Z 0 0 v C (� 400 400 m m c> CO Cry 81100 End Rid ✓ iBId:SHOO ✓ 13-3/8"..• KOP Bid 1.51100 V 0 s e o 0 9- RTE End Cry End Cry -400 -400 Cry 3/100 _ Cry 3/100 End Cry 93/8"Csg -800 -800 Cry 3/100 End Cry -400 0 400 800 1200 :<< W Scale=1(in):400(ft) E >>> Chevron %. Schlumberger %0 - M-11 (P10) I FlE`° Trading Bay Unit STRUDTURE Steelhead MMvo�pnslc Porvmele,. I 5.440.La2O.2 61023 AeMMa Sale Plane,Zone 04,US Feet Misalarimua BOOM 2010 Oh'. 13652' DWe: Nwembx 10,2010 Lat' N 60,95,.,66 N2IIbMN: 249945.54IUS 044 Dom:�138032013' S. by01 slot 12 TVDRM: RMary Taba(1608 above Mean Sea Level) Map Dec'. 18033' FS: 55526457 Lon: W 15136 9.192 BMap: 214073.180US Smle Fxl:299659304 Pan: M-11(P10) Sr,Dale:*most 23,2010 -800 -400 0 400 800 1200 (.0 t •8R'• u'.' "_.•,I1 RDo II I( RD oM-1 ,.1 .:1 10€29 0. ,tif 2000 • 12 RD8 • DF, 2000 4 • 4l„Tv')• 399,.•<49 ' rtz. lf 69971z -09 t i 77411l -04 1600 h1/4,b, . , / / rliz t• 'NA NJOIFF9i,fr ,44° , Ipp,,,,,iw .:, • • .,„4 4 , „or -24 RD •1 TVD . ., .„ .„ .N ,,,d . � / o 1200 a�`� z9v7T,Dii, .1/41. � �` -1� ,Lif o � �t-34RD N a' G-2 RD A I� 7 o±# e 800 4P� 0 g 44 • 0 400 •////'4,./0 a a• , 400 To 14,V--:. , ,�2elief► 22ooc,,s�411. � /. iik :08 .. •cn •�1 V o •9aa,j O \M /® 4561 TVD .leik 08RD •z 1.•0° •I5°b• -•0 % 1 , ` • 4562 TVD •-I RD2 ',`D \ ,006,v0.zM•4 , -400, ' k ,oe-400 <9 • ,Fe°T n - -400 ON G-30 1 • it N • ,0611 6 Iva \ M- \'C'19• 7�)' .2.°6'PY _06G-12RD3 .2„ a -800 Boo r • o .1061/"' G-26RD 16-1BM-17 G-031EMIII8"0l' .:IMER M-' PIB3-33DPN -800 -400 0 400 800 1200 «< W Scale= 1(in):400(ft) E >>> Steelhead M-11 Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE 17-1/2" Hole Section • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well v control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1 . Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 6. Perform diverter drills until the crews are familiar with the procedure. • M-13, M-20,are all critical close approach wells. Record annulus pressures on these wells prior to v spud and monitor during the drilling of the surface and 1st intermediate hole sections. 12-1/4" Hole Sections • Shallow gas sands will be encountered that have the potential to flow and cause a loss of well control. All operations shall proceed with the necessary precautions to prevent a kick. Special attention is required in the following areas: 1. Monitor trip tank on each trip into and out of the hole. 2. Carefully monitor PVT for gain / loss. 3. Have LCM material onboard and ready for use in the event significant losses occur. 4. Minimize surge and swab pressures while tripping. 5. Review cement spacers and washes to ensure the well is not under balanced at any point during cementing operations. 8-1/2" Hole Section • Significantly under pressured reservoir sands will be encountered A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/trip ping the intermediate interval. • Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures • Differential sticking is a considerable risk while drilling these depleted sands. Keep the drill string moving whenever possible. • Numerous coals will be drilled through. Unocal coal drilling strategy; limiting the amount of coal drilled (<10') prior to back reaming should be followed. HYDROGEN SULFIDE - H2S • Steelhead is designated as an H2S drill site. Standard Operating Procedures for H2S V precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies 09N13W28 09N13W29 40, > 1600 ADL017594 ADL01730 1-11 Proposed 09N1 3W32 09N13W33 Chevron McArthur River Field 0 sari ,aca IWO of California U ion d11 Company Feet Steel head Platform Mean State Flare Zorroe 4 NA.,192:7 M-11 Proposed September 13,2010 3 C a) E N U a) O 0 N _o U O p) U Q 0 N 0 O o - U 0 D a) 0 4- C E — O NN 0 65 vi O a 3 N II s ^ ° aLo 2 0 - rn 0) U d � � r 0 * M ci a) 3 ti, a) N co p a J o_ NN v) w O (#, Q O OC \ aa = b O 25 O 5 _N c O. N. > n c6 0 cf v O N .N p. _ O O N II U N ON _� II O O w II N II + cco — — a) O U _o o E c +- N LO s= � U No O a N _D C a) * N 0) O M O OpOp II N * II > t. 0 C NII N O 0 N O a U ° e 0 E U II E > > a) U 0 j 5 75 > o E > No � E °U ° N o d) c a c 3 - r 5- s✓ `' (N O vi a N O O a a) N p O 0 N U O cn � U Qco U i30c N 0 ° M co °' U, V * cn c? c? Z a• N C a) E a) a• o 0 (-7-, N —L N C _o a) U E 0) a) a 0 a 0 \ p N 4 N N N 0 n � 0 0) o 4 0 a C N O C II a , II ( aLU 0 LU d . 8 O N ( N N N ..- t3 a) 0 N co O 0 � y c N O . N O 't �.Q - N O o h Q 0tCOO = NCKI= p O N O —" O II - N Q +- �o 0 N O p II N 0. o. C p `O N If) CO O . - `o ,o `o co + 4 d• CO + 0) O II O LU c 0 II O 7, 0 N p N •7, 1- V) d• N U IQ o o II U o v '" II Q) c X II O 0 x II N N N 0 0 4) 0 o o) g E o 0 v) E _O 0 o � j 0 0 a) 0 N v O N 3 >3ai o o E o N g) E o D j p - - = O 6 a E > N a E > N 0 > _ t � 4) = O +- a) = o '- tll D N ' U Ovvi U OU s a) oo Co LU LU V o. Z N. y- N C cn O .N O -0 CDQ cv. Q o co co E o L o N ON II t N Lf) O EC v � � . 15 13 .4 rn 0 a) co fwq to) p O H `a II in0 c) 25 igi N \p - O N O = ö OM p + O 7O N II OLo OOc II co II O E 00 p O O O II Cco ii- O II E /O c > •° 3 > Q c N N E o O E C O D O = N o > o 0 C o Q = o 0 O U Q C O ZS U 12- 9N O N N V U 1 Chevron Maximum Anticipated Surface Pressure Calculation Steelhead Platform Well M-11 Cook Inlet,Alaska Assumptions: 1. At TD the nearest well is G-21. Based on offset drilling &well test data from G-21, the maximum pore pressure gradient is predicted to be a 0.435 psi/ft gradient(8.36 EMVV)from surface to planned total depth at 8950.0 TVD BRT. 2.The 17''A"surface hole will be drilled to approximately 1420'/1410' MD/TVD under an existing structural pile conductor and will use a diverter system for well control. The diverter system is not designed to shut the well in and contain pressure. Therefore,MASP is 0 psig for this hole section. 3.The M.A.S.P.during drilling operations will be governed by pore pressure at TD. The calculations take into account a gas gradient to surface of.1 psi/ft. 4.The M.A.S.P.during production operations will be the estimated SIBHP minus the gas hydrostatic pressure between TD &the surface. 17.5"Hole Fracture Pressure Conductor(470 TVD): Max. Est. Frac pressure at KOP= 470 ft. x 0.000 psi/ft = 0 psi M.A.S.P.from pore pressure: Max. pore pressure at T.D. = 1,410 ft. x 0.440 psi/ft = 620 psi M.A.S.P.(tbg leak at surface) = 550 psi -(0.1 psi/ft*1410 ft)= = 409 psi 12.25"hole Fracture Pressure at Casing Shoe(1230'TVD) Max. Est. Frac pressure at 13 3/8"shoe= 1410 ft. x 0.866 psi/ft = 1221 psi M.A.S.P.from pore pressure: Max. pore pressure at T.D. = 6,088 ft. x 0.440 psi/ft = 2679 psi M.A.S.P. (tbg leak at surface) = 2679 psi -(0.1/psi/ft"6088 ft)= = 2070 psi 8.5"Hole Fracture Pressure at Casing Shoe(8950'TVD) Max. Est. Frac pressure at 9 5/8"shoe= 6088 ft. x 0.866 psi/ft = 5272 psi M.A.S.P.from pore pressure: Max. pore pressure at T.D. = 8,950 ft. x 0.435 psi/ft = 3893 psi M.A.S.P.(tbg leak at surface) = 3893 psi -(6.1 psi/ft*8950 ft)= = 2998 psi u 1 U K v ., 1. 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W y tel tel te) In O) Ql (N C 7- a V V V O O O O O O O SI— Ca /L^ V t O ❑ Cn F' M N ci 0 0 O t 00 Ol 00 c0 to O -C d ❑ 71 N J N 0 U) T Q .-.i Ql O co L M l) N 7 Lf) 00 N M r1 00 a N M M M M N M > N O a co ca a rcs c N N N m 2 0 Y O Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT/LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre-determined equivalent mud weight. • Leak-Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak-off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak-offs. • Open Hole LOTs (OH LOTs)- Leak-off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak-off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: l 1. Drill 20' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the formation below the surface shoe is taken to leak-off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak-off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open-hole LOT is performed. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Chevron %. Schlumberger WI "E" M-11 (P10) FIELD Trading Bay Unit STRUCTURE Steelhead Magn•Ik Pann4e! 5474$.Loolbn NA027 A0Gga SlAt Plats,Zoe 04,U5 FGGI I Miecellamoue MOEW'. 900443010 06: 13552' Date: November 10,2010 Lot: N 80195../85 NalM1i�g: 2449456 S49U5 0440049:-I.39933073' Sbi: lag Al slot 12 TVD RW'. Rotary Ta50(19011a5o9.Mean Sea Level) Map Dec:18073' F5: 55528An7 Lon: W15138 8.752 Easting. 214073.78(WS Sob Fac:0.99999303 Plan: M-11(P10) Sno DWG:August 23,3010 -800 -400 0 400 800 40 1200 t 18R•k K.: -4 ,,-`).ii RDa , '(,RD M_i n . ..:1 12E29 vi 2000 12RD2 G ,,o v� 2000 O • • ,,.7VD I ! Ij . 97 09 Nhib ,. Akprii0 k -04 1600 /419141Sb°�2D ACRD .t rvD,. li,,,'..,'`ht.• f . •ir'4 •,__4407 1200 — }9� ,,, •e 34RD N , Fir,,g1,4 4555T e�� / -2 RD 4A +. 1 a i i -24 Z � 800 likitti / -/4.. li'ilk V4ir .r 44/11,1". 1 ''' r_ 'I,� 800 o 1 •4.y RD y • Ilk • • II - 'ef Well 1 .1IS) -10,. .400 1c J 'i141 400 co � elief - 22000; �! I " A . B1-2 Nik �ei -08 V • 6pj1TVD D ,/��,!�� , V •9aglty `\pr, 7Sa/�/� r a561TVD 08RD ' l •2 -,,F,140 tl SOy1 -.0 • \ ,tA6 4562 ND • -12 RD2 I)-° \ • 3692.3 ' M.! - • 200 � , , -400 ` n-30 n a4 -400 G-30 M- ' '> . ,06)1 • `° • 7%1 r '°°n,4 -05 -12RD2 •11.,1 -,1*. -800 -800 O •10611N G-26RD 'F -t M-17 G-031IE-SS-or .:IMRE M-t@R3-33DPN -800 -400 0 400 800 1200 «< W Scale= 1(in):400(ft) E >>> M-18 20 3/4" BOP/Diverter Stack up ( 21 1/4"2M \ Hydril Annular 4.22' I I HUB CLAMP M Hydril DBL Gate 'Ipe Rams 4.71' 20 3/4" 3M Blind Rams I i HUB CLAMP f 20 314" s r� � Mud Cross r HCR 2.00' L I HUB CLAMP I I 7f10 20 3/4"3M Single Gate 2,71' HUB CLAMP 6"Ansi 600 Diverter Valves 20 3/4 3M 2.00 NT2 Connector XO ---_. Diverter Spool 3.00' 0111111 20 3/4 3M NT2 /• Connector 20 3/4"3M Riser 20 3/4"3M Riser VETCO 20 3/4" NT2 Connector VETCO NT2 HEAD 6"ANSI 600 RTJ C : Ic a 111- - -- _ ��A1 v � i. � -- --gym o w N •• W rU� Q a • u LT, Y z p a e —. p W G 4 _ . __ - 7 In 0 ....i....ix _ N ' v l - Q,' U. f" I .s n o in I r o F T � • 4 4 W I I Irt I w 1. p r- , z `y,Cs x T w I f w F- X Tr . - v, U ., ;; .. d (.., al, _E_h_l irk ,itiffe I_ ,.-J.– g r . - iii 1 w 1 • J • MPT —117r- • • .-.--TN\\.. 111111.111.111 r •.--..;\\-- .c . . u •,-,. , , - •tvii)-- - —II ____0 I1 TRANSMITTAL LETTER CHECKLIST WELL NAME I dit / PTD# Z/C' / y ' +/ Development Service Exploratory Stratigraphic Test Non-Conventional Well / // FIELD: 41/11 .� //`r � G -tom POOL: /(�"l c cid / tui '° ,'__ / Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 E N O O Iico) O C.7 ' . . N • N • Ocv 3a E C • a N. 0 •0' E a O' .c c O. o n) a o N N. •_ y o ' C' 3' a) a° . . . w cn • E. a o E o a co. coco , y f0 E 0 o, p a m o 4. -12'�, U. m oi, w,. al TD- 3' 3 >. o' a) o E o - O 4 a) c a E m « a), Q. N, () N' ' a> � � 0 p 7, y 0) 0, a, >>, O �, �� �� C •C, CO, CO. L C 6) C O C @ W. N , _ E 00 N = U, C, y 'C E .c 'C f/) N N' 0 0 o •0 C Z .! 0 m _ E. 0. :3 )' o >- r- �' O G coL M. Z 0' O cox m W y y. N, N' a) CO C O J. Y. L. O, y c N Z �. 0, N. 8. y. a < g a, a). N. b• .I o, Q% y. p. p. 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U, a. a, Z, U, cn c.), c.�, 0 U a, w ¢ o m m, U, 3' N', 2 a. 0, v>, cn, c.), co W O N M -cr p h co OO N M )cO n O N NNN N lN O r(N.; N O O M NM M V u) CO rM CO O M M 0.1g. 0 0 o O •• F-1 w o m o m 0 cCC0 C Np NR CO N V 0 W 10 .0 0 M m G O O N W A 01 c co O 0. 4 o u) `m T 0 E J #t C 0. c ` Q p 0 O p W a a 4 wco CL$ q o 0 S Q c0 V/ell History File APPENDIX Infoimation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1 Company Chevron Alaska 1 Schlumberger Well Name M-11 1 Chevron %101 Field Name McArthur River Field 1 Rig Nabors 51 - Steelhead 1 State Alaska 1 Report By R.Heath Report Date 17-Dec-2010 / IILogging Date 11/25/2010 \� I API Number 50-733-20590-00 24 Recorded By M.Zaripov Stethoscope 825 • Final Report Innovations in Formation Testing DCS Analysis: Combined Runs 2, 3 and 5 1 Company Chevron Alaska Schlumberger Well Name M-11 Chevron %10 1 Field Name McArthur River Field %rn. Rig Nabors 51 - Steelhead 1 State Alaska II 1 Report By R.Heath Report Date 17 Dec 2010 Logging Date 09-NOV-10 API Number 50-733-20590-00 Recorded By M.Zaripov/B.Warta StethoScope 825 • Final Report Innovations in Formatio Testing DCS Analysis Report - Run 2 & Run 3 Written Comments Schlumberger I Objective: To compile a StethoScope evaluation report that includes plots of formation pressures versus depth, a table of test point data, and individual plots of each test draw-down/build-up sequence. Comments: Bit runs 2 and 3 were conducted with the StethoScope FPWD825 tool between 09-Nov-2010 and 15-Nov-2010 in the 12 1/4" hole, from approximately 1650 ft to 6374 ft(measured Depth). A total of 16 tests were attempted and data was successfully acquired for all 16 tests. Overall, the quality of the tests was good. 7 of the tests were interpreted as "Tight'and the remaining 9 were labeled "Good". The test quality is graded by color, with Green being the highest(see the table below for grading explanation). ' All but one of the tests in this intermediate hole section were acquired using the Time Optimized Pretest(TOP)2-C sequence, as noted in the Test Point Table. The last test of Run3 was made using the TOP 2-D sequence in an attempt to determine if this was a more appropriate sequence. In the given environment,very little difference exists between the two test types. Formations testing "tight"with 2-C tests more than likely will also test"Tight" under the 2-D sequence. The data used to generate this report was the Recorded Mode FPWD825 StethoScope data in LAS format, processed using PD-Plot software (Vers 7.1.56). TVD depths were calculated usingthe surveydata supplied bythe field engineer. The GR, TNPH, ROBB and Resistivitycurves P PP 9 shown for correlation were obtained from the ARC/ADN surveys run simultaneously with the StethoScope tool. Color Quality# Description Examples Red 0 through 3 No Formation Pressure No Seal or Lost Seal Yellow 4 through 7 Questionable/Fair Formation Pressure Tight-Not Close to Being Stabilized Green 8 through 10 Good Formation Pressure Build Up-Stabilized or Close 1 M-11 2 I Schlumberger Formation Tops Table Formation Tops Table I Source :Customer Formation Tops MD(ft) TVD(ft) Sub Sea(ft) Color SZ12 1648.01 1626.98 -1466.98 SZ17 2117.02 2061.29 -1901.29 I SZ22 2607.99 2485.34 -2325.34 A6 3286.89 3077.21 -2917.21 B3S 3544.98 3316.2 -3156.2 B4S 3647.94 3414.13 -3254.13 I B5 3791.88 3553.23 -3393.23 B6 3875.91 3635.42 -3475.42 B7 3993.99 3751.65 -3591.65 Cl 4145.01 3900.65 -3740.65 I D3B 4994.01 4737.49 -4577.49 D6 5300.01 5037.3 -4877.3 D16C 6322.28 5995.51 -5835.51 I I I I I I I I I I I I M-11 3 Schlumberger Test Point Table Test Test Test Test Formation Last-Read Last-Read I No. Run MD TVD Subsea Pressure Test Type FPWD Quality Invest. I Buildup {Buildup ft ft ft .psia psia I psia i 1 2 ,1649.66 1628.56 -1468.56 470.14 ;Type 2 C Good test. Final still building ,470.67 `470.22 I Radial Time Function. i 2 2 12135.25 2077.67 -1917.67 315.62 Type 2-C Tight test 891.74 315.62 I 3 2 12140.49 2082.37 -1922.37 255.16 Type 2 -C ,Good Test. Final BU still 276.97 255.16 building moderately 4 2 12612.67 2489.28 -2329.28 878.2 Type 2 -C Tight test 1225.9 878.2 5 2 3295.99 3085.38 -2925.38 390.96 2 rype Good Test. Final BU still 392.62 390.96 C building 6 2 3589.95 3358.74 -3198.74 323.39 Type 2-C Tight test 152.84 323.39 7 2 13650.94 3416.93 -3256.93 301.59 Type 2-C Tight test 305.57 301.59 I 8 2 I 3641.08 3407.49 -3247.49 272.78 Type 2-C Tight test 272.78 9 2 13834.93 3595.15 -3435.15 255.85 I Type 2-C Good test. Final BU still building 255.93 255.85 10 2 13934.90 3693.37 -3533.37 355.98 Type 2-C Tight test 355.98 11 2 I 4034.97 3792.05 -3632.05 549.88 I Type 2-C Good test. Reasonable 60s 550.39 549.88 slope 12 2 4167.43 3922.76 -3762.76 460.88 Type 2 C Tight test 460.88 II1 3 4998.06 4741.44 -4581.44 805.6 I Type 2 C Good Test, Stable BU Low 60s 805 805.6 slope 2 3 5324.15 5060.94 -4900.94 667.44 Type 2-C Good Test. Stable BU Slightly '667.57 667.44 I Neg. 60s slope 3 3 I 6373.94 6039.87 -5879.87 255.44 I Type 2-C Good test. Stable BU-Slightly 255.04 255.44 Neg. 60s slope 4 3 ,4850.04 14596.36 -4436.36 377 I Type 2-D Good test. stable BU-Slightly 376.98 377.04 ii Neg. 60s sbpe I I I I. I M-11 4 , I Schlumberger Test Point Table Test Drawdown :Mud Mud FPWD Time& Pretest Pretest Pretest I No. Mobility Before After Pressure 60 s Slope Date Volume Time Flowrate Temp. Variance I md/cp i psia psia s psia psia/min cc s cc/s DEGF 1 ,10597.27 180101 799.39 0.03 0.03 ,09-Nov-201 1016.95 15 67.8 92.79 ii 00929:41 I 2 27.92 1034.46 1031.08 0.03 1.5 09-Nov-201 5.15 64.5 0.08 99.36 0 14:36:11 3 10.27 11029.46 1027.25 0.03 2.42 09-Nov-201 8.6 28.06 0.31 99.88 017 0 15:02:59 I 4 16.4 1249.83 1244.32 0.35 -2.28 09-Nov-201 0.53 1.25 0.42 103.21 0 19:57:01 5 2.12 1155828 1557.12 0.1 2.16 10-Nov-201 8.26 28.19 0.29 105.69 I 0 0437ta59 6 0.15 1626.7 1624.35 0.14 16.9 11-Nov-201 0.54 1.19 0.45 102.58 0 02:56:38 7 0.31 1657.35 € 1658.29 0.1 15.3 11-Nov-201 1.06 7.81 0.14 104.18 I 0 04:48:06 1 8 0.23 1653.59 1651.78 0.06 12.15 11-Nov-201 0.54' 1.25 0.43 102.96 0 05:06:36 I 9 93.4 1 1750.42 1749.46 0.09 -1.27 11-Nov-201 ;8.54 28.06 0.3 107.49 0 08:43:34 10 0.17 1803.15 1802.73 0.06 17.14 11-Nov-201 ;0.54 1.38 0.39 107.55 0104306 I 4413.12 1847.24 1844.74 0.04 0.14 11-Nov-201 1024.34 15.25 67.17 110.12 01301:38 ' .-ots,, 343.81 1927.41 1925.63 0.05 12 12-Nov-201 1003.02 1.25 802.42 113.88 I 0 07:33:02 1 65.13 2353.84 2349.03 0.28 0.03 14-Nov-201 7.17 7.19 1 111.9 0 03:08:41 I 6. 0 9359.04 2518.52 2512.54 0.19 -.01 14-Nov-201 1024.35 7.38 0 08:37:20 138.89 116.33 q2062.79 2963.98 2963.61 0.26 04 15-Nov-201 1017.14 14.69 69.25 122.54 0 05:51:54 I 341.67 12322.94 2291.27 0.06 -.03 15-Nov-201 7.51 7.56 0.99 119.55 � 020:59:40 I I I I I I I M-11 5 Schlumberger Test Point Summary Table 1 Test Types Quantity Type 2 - C 15 Type 2- D _ 1 TOTAL 16 Gauges AQAP 16 Runs I Color 2 12 3 4 Formation Pressure Quality: Color 0(no pressure) - 10(best) 10 9 7 7 Drawdown Mobility Quality: Color 0 (no pressure) - 10(best) 10 5 7 10 4 1 1 1 1 1 1 1 1 1 1 1 M-11 6 I Schlumberger Header 1 ICOMPANY: Chevron Alaska IWELL: M-11 FIELD: McArthur River Field BOROUGH: Kenai STATE: Alaska StethoScope I Schlumberger Bit Runs 2 & 3 Formation Pressures While Drilling 7, Y Elev: K.B.0 ft I a G.L . 185 ft a2 o D.F.160 ft g` 7Y 0 m Permanent Datum: Sea Level Elev:0 ft U o Log Measured From: Driller Floor 160ft above Perm. Datum Drilling Measured From: DF I o a STATE Max Deviation Latitude Longitude Et D v m E m LL 3 8 60°49'54.487"N 151°36'8.762"W Lo••in. Date 11/9/2010 Run Number 2 I Depth Driller 0 ft Schlumberser Depth 4735 ft Bottom Los Interval 9847 ft I To• Los Interval 0 ft Casin. Drillin• Size @ Death 13.38 in 1430 ft Casing Schlumberger 0 ft Bit Size 12.25 in T •e Fluid in Hole Gel Chem Densit Viscosit 9.2 lb/•al 47 c• Mud Fluid Loss PH 0 ml 9.1 Source of Sample Active Tank I RM @ Measured Tem•erature 0.24 @ 0 DEGF @ RMF @ Measured Tem.erature 0 @ 0 DEGF @ RMC @ Measured Tem•erature 0 @ 0 DEGF @ Source RMF Source RMC Pressed I RM @ MR RMF @ MRT 0.15 0 DEGF 0.13 0 DEGF--_- Maximum Recorded Tem•eratures 114 DEGF 0 DEGF 0 DEGF Circulation Sto••ed Time I Loeser On Bottom Time Unit Number Location Recorded B B.Warta/M.Zarapov Witnessed B S.Hauck I I I M-11 7 Hookload Plot It has been learned on previous jobs to reduce Lost seals and packer damage, before every depth set to observe the up weight and down weight and set the tool in the mid-range, known as the rotating weight, irrespective of rig type. Below is shown the test weights for this job, between the up and down weights: 0 50 100 $okload 2nbs 250 300 350 1500.00 2000.00 2500.00 1 3000.00 3500.00 ' [1000.00 4500.00 60 5000.00 5500.0 \ak _ 0 1D '" 600 00 6000.00 \\ 1 6500.00 1 Test Weight ' DN Weight Rot Weight 1 UP Weight ' I 1 8 I Schlumberger Inclinometry Tables 1 M-11 Source :Supplied Survey table I MD TVD Devi Azimuth North East Departur Departur Dogleg e e Severity Azimuth ft ft Deg Deg ft ft ft Deg Deg/100f I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 264.71 264.71 0.08 221.49 -0.14 -0.12 0.18 220.60 343.27 343.27 0.45 180.89 -0.49 -0.16 0.52 198.08 1 427.97 427.96 0.86 187.94 -1.45 -0.26 1.47 190.17 0.48 487.53 487.52 0.33 19.75 -1.73 -0.26 1.75 188.55 0.89 521.31 521.30 0.75 14.71 -1.43 -0.17 1.44 186.78 1.24 554.75 554.74 1.07 16.67 -0.92 -0.03 0.92 181.87 0.96 I 582.53 582.51 0.71 20.61 -0.51 0.11 0.52 167.83 1.30 610.94 610.92 0.45 12.50 -0.23 0.19 0.30 140.44 0.92 640.65 640.63 0.29 17.30 -0.05 0.24 0.25 101.77 0.54 670.81 670.79 0.02 178.05 0.02 0.27 0.27 85.76 0.90 I _701.06 701.04 0.28 292.74 0.04 0.20 0.20 78.69 0.86 731.73 731.71 0.50 305.73 0.15 0.02 0.15 7.59 0.72 763.71 763.69 0.70 290.00 0.30 -0.28 0.41 316.97 0.63 795.91 795.88 1.08 271.80 0.38 -0.77 0.86 296.27 1.18 I 826.02 825.98 1.73 273.03 0.41 -1.50 1.56 285.29 2.16 855.39 855.33 2.55 263.48 0.36 -2.59 2.61 277.91 2.79 890.63 890.52 3.56 267.80 0.23 -4.47 4.48 272.95 2.87 I 922.29 922.11 4.30 272.08 0.23 -6.64 6.64 271.98 2.34 952.13 951.85 4.99 274.90 0.38 -9.05 9.06 272.40 2.31 985.53 985.11 5.53 276.75 0.70 -12.09 12.11 273.31 1.62 1080.42 1079.27 8.59 282.83 2.81 -23.54 23.71 276.81 3.22 I 1175.34 1172.78 11.24 269.75 4.34 -39.71 39.95 276.24 2.79 ___ 1270.21 1265.35 14.00 273.53 5.01 -60.42 60.63 274.74 2.91 1365.06 1356.85 16.52 265.70 4.71 -85.32 85.45 273.16 2.66 1390.11 1380.83 17.18 264.05 4.05 -92.55 92.64 272.51 2.63 I 1456.12 1443.85 17.44 259.47 1.24 -111.98 111.99 270.63 0.39 1551.01 1534.44 17.27 250.60 -6.04 -139.25 139.38 267.52 0.18 1645.75 1624.84 17.66 239.30 -18.05 -164.87 165.86 263.75 0.41 I 1740.54 1714.74 19.34 230.68 -35.34 -189.39 192.66 259.43 1.77 1835.38 1803.61 21.58 223.41 -57.97 -213.53 221.26 254.81 2.36 1930.24 1891.38 23.07 215.23 -85.83 -236.24 251.35 250.03 1.57 2025.07 1978.14 24.59 207.76 -118.48 -256.16 282.23 245.18 1.60 I 2119.76 2063.77 25.99 201.71 -155.20 -273.01 314.04 240.38 1.48 2213.67 2147.55 27.73 198.44 -195.05 -287.54 347.45 235.85 1.85 2309.41 2231.54 29.64 195.67 -238.98 -300.98 384.32 231.55 1.99 2404.30 2313.10 31.81 193.89 -285.85 -313.32 424.12 227.62 2.29 I 2499.22 2393.51 32.40 193.63 -334.85 -325.32 466.86 224.17 0.62 2594.08 2473.59 32.43 193.09 -384.33 -337.07 511.20 221.25 0.03 2688.98 2553.73 32.34 194.33 -433.70 -349.11 556.75 218.83 0.09 I 2783.85 2634.01 32.05 194.23 -482.69 -361.58 603.10 216.84 0.31 2878.66 2714.83 31.00 194.08 -530.76 -373.71 649.13 215.15 1.11 2973.53 2796.99 29.00 191.35 -577.01 -384.18 693.21 213.66 2.11 3068.37 2880.59 27.35 189.21 -621.06 -392.19 734.53 212.27 1.74 I 3163.06 2965.14 26.15 189.55 -663.11 -399.13 773.96 211.04 1.27 3257.75 3050.62 24.82 188.68 -703.33 -405.59 811.90 209.97 1.40 3352.52 3137.10 23.45 186.84 -741.72 -410.84 847.90 208.98 1.45 3447.28 3224.63 21.61 184.64 -777.84 -414.50 881.39 208.05 1.94 I 3541.73 3313.11 19.36 3636.52 3403.15 17.04 180.69 -810.83 -416.10 911.36 207.17 2.38 177.30 -840.42 -415.63 937.58 206.31 2.45 3731.42 3494.42 14.73 171.73 -866.25 -413.24 959.77 205.50 2.43 3826.22 3586.64 12.05 165.64 -887.77 -409.05 977.48 204.74 2.83 I 3921.05 3679.74 9.88 160.06 -905.01 -403.82 991.02 204.05 2.29 4015.92 3773.27 9.48 146.51 -919.18 -396.73 1001.14 203.35 0.42 M-11 9 Schlumberger Inclinometry Tables 4110.75 3866.85 9.27 131.77 -930.78 -386.73 1007.92 202.56 0.22 I 4205.67 3960.50 9.58 118.34 -939.63 -374.07 1011.35 201.71 0.33 4300.43 4053.96 9.50 102.88 -945.11 -359.50 1011.17 200.83 0.08 4395.24 4147.47 9.59 89.43 -946.78 -343.98 1007.33 199.97 0.09 I 4490.04 4241.07 8.78 73.39 -944.63 -329.15 1000.33 199.21 0.85 4584.83 4334.78 8.67 56.44 -938.61 -316.26 990.46 198.62 0.12 4674.78 4423.68 8.94 41.32 -929.61 -305.99 978.67 198.22 0.30 I 4769.67 4517.32 9.69 35.49 -917.57 -296.49 964.28 197.91 0.79 4864.43 4610.49 11.32 35.66 -903.52 -286.44 947.84 197.59 1.72 4958.64 4702.84 11.52 35.56 -888.36 -275.57 930.12 197.23 0.21 5053.44 4795.71 11.59 34.57 -872.82 -264.67 912.07 196.87 0.07 I 5148.25 4888.60 11.56 34.82 -857.18 -253.84 893.98 196.50 0.03 5233.10 4971.74 11.45 34.37 -843.24 -244.23 877.90 196.15 0.13 5337.90 5074.43 11.58 33.47 -825.88 -232.56 858.00 195.73 0.12 5432.90 5167.50 11.55 33.05 -809.96 -222.11 839.86 195.33 0.03 I 5527.80 5260.37 12.23 33.35 -793.60 -211.40 821.27 194.92 0.72 5622.78 5352.74 14.62 31.26 -774.95 -199.65 800.25 194.45 2.52 5717.62 5443.96 17.14 30.66 -752.69 -186.31 775.41 193.90 2.66 5812.58 5534.18 19.18 33.30 -727.61 -170.61 I 747.34 193.20 2.15 I 5907.03 5622.82 21.24 36.24 -700.84 -151.97 1717.13 192.23 2.18 6002.42 5711.00 23.59 38.27 -671.92 -129.93 684.37 190.94 2.46 6097.32 5797.28 25.62 40.96 -641.51 -104.72 650.00 189.27 2.14 I 6192.10 5882.01 27.63 43.65 -610.13 -76.11 614.86 187.11 2.12 6286.92 5965.19 29.73 43.13 -577.06 -44.86 578.80 184.45 2.21 6381.83 6046.57 32.18 43.80 -541.63 -11.27 541.75 181.19 2.58 6466.19 6117.23 34.04 44.11 -508.47 20.71 508.89 177.67 2.20 I 6567.35 6199.99 36.16 43.89 -466.62 61.12 470.61 172.54 2.10 I I I I I I I I I M-11 10 ' Schlumberger Well Path Plots Ma• View 1011.35 1 I I North - South (ft) 1t -1011.35 1011.35 West - East (ft) 1011.35 ' Cross Section View 264.71 TVD (ft) 6199.99 -1011.35 Departure (ft) Plane = 201.7 - 21.7DEG) 1011.35 M-11 11 Schlumberger Pressure Depth Plot FORMATION(AQAP psia) MUD BEFORE 1:7086 ft DRAWDOWN TNPH(pu) ROP5(ft/h) I (AQAP psia) MOBILITY(AQAP and/cp) 0 1000 < TVD (MD) 0 60 0 500 0 0 3000 0.1 1000 ROBB(g/cm3) ECD(Ibm/gal) MUD AFTER (AQAP 1.65 2.65 8 13 psia) { 5 8 > 1.1.2. i_ o o 0 o Yoyer 000 o TEMPERATURE (AQAP degf) 0 3000 A34H(ohm.m) 90 190 GR(gap') 0.1 1000 0 150 P16H(ohm.m) 0.1 1000 l�ll� lil II { 1 O 1 t-1 I - I iil -_ 7 � — All �� II -gi 2000 T..! 7 '16,�1s;� II 2 0 0 2 _ (2049.2) . — - t- :=!.!.:=_-,d== �ai� —511 -4 IIID- _1 ' 3000 :;; leim iiiii _ _I 2M=___Mil — 5 0 5 � i (3201.7) 1 11 EOMI® -- - _______e I i ��a - -x_z 1 Q976 Y �.:r: IIID Ali M g0 9 P. * 9 SEN 10 10 _ {} 10 f Illli 9 im M 11 O 11 • 11 IIi R i { -2 0 12 s '2 ip�- 1� � �~� 4000 I ink _ -__W�- m i 4245.0 1II� 111 l� id Al-iii. ill ----_--4/ '11 G 4 4 mLG' 0 41 lis=- ii: A _63. y I 5000 -. 2 0 2 .1` :O. 2 (5261.9) Ill "gym _ -- i _ ll -�m ' - .. a- - Illy w i iii., IAMI ii , —- ._ _ _ fiil = I 6000 D1: — : ,•"----' 1 0 . 3 lEtt lir" 327.5) _ .1 M-11 12 I Schlumberger XY MUD Before vs MUD After 2970.00 3 1 1 2 41 Mud Pressure After(psia) 12 11 10 111 9 5 4 2 790.00 1 790.00 Mud Pressure Before(psia) 2970.00 1 I M-11 13 ••:1- 1 C. 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N 1 Company Chevron Alaska Schlumberger Well Name M-11 1 Chevron 1%0 Field Name McArthur River Field 1 Rig Nabors 51 - Steelhead 1 State Alaska 1 1 Report By R.Heath Report Date 17-Dec-2010 Logging Date 11/25/2010 1 API Number 50-733-20590-00 Recorded By M.Zaripov StethoScope ��� .�a � �� . . Final Report Innovations in Formation Testing DCS Analysis Report - Run 5 PD Plot 7 Ver 7.1.56 Written Comments Schlumberger I Objective: To compile a StethoScope evaluation report that includes plots of formation pressures versus depth, a table of test point data, and individual plots of each test draw-down/build-up sequence. Comments: I Bit run 5 was conducted with the StethoScope FPWD675 tool between 25-Nov-2010 and 27-Nov-2010 in the 8 1/2" hole,from approximately 8942 ft to 9846 ft(Measured Depth). A total of 9 tests were attempted and data was successfully acquired for all 9 tests. Overall, the quality of the tests was very I good. All 9 tests were labeled "Good". The test quality is graded by color, with Green being the highest(see the table below for grading explanation). All of the tests in this production hole section were acquired using the Time Optimized Pretest(TOP) 2-D sequence, as noted in I the Test Point Table. The data used to generate this report was the Recorded Mode FPWD675 StethoScope data in LAS format, processed using PD-Plot software (Vers 7.1.56). TVD depths were calculated using the survey data supplied by the field engineer. The GR, TNPH, ROBB and Resistivity curves shown for correlation were obtained from the EcoScope survey run simultaneously with the StethoScope tool. Color Quality# _Description Examples I Red 0 through 3 No Formation Pressure No Seal or Lost Seal Yellow 4 through 7 Questionable/Fair Formation Pressure Tight-Not Close to Being Stabilized Green 8 through 10 Good Formation Pressure Build Up-Stabilized or Close I I I I I I I I I I I M-11 2 ' ' Schlumberger Formation Tops Table Formation Tops Table Source :Customer Formation Tops MD(ft) TVD(ft) Sub Sea (ft) Color MST 8903.99 7943.98 -7783.98 F14BST 9114 8096.56 -7936.56 ' F15BST F16ST 9220.01 8173.21 -8013.21 9384.99 8291.98 -8131.98 GO1ST 9543.99 8406.56 -8246.56 GO3ST 9705.03 8522.86 -8362.86 GO5ST 9806 8595.74 -8435.74 1 1 1 1 1 1 M-11 3 Schlumberger Test Point Table File Test Test Test Formation Last-Read Last-Read I No. Run MD TVD Subsea Pressure Test Type FPWD Quality Buildup Buildup Invest. ft ,ft ft psia psia psia 1 5 8942.09 7971.66 -7811.66 2729.8 I Type 2-D Good test. Stable BU-low 60s 2729.66 2729.8 slope 2 5 8956.02 7981.79 -7821.79 2730.75 I Type 2-D Good test. Stable BU-low 60s 2730.26 2730.75 slope I 3 5 ...266.04 8206.37 -8046.37 3176.25 •Type 2-D Good test. Slightly Neg. BU- 3175.99 3175 Spher. Time Func. 4 5 9342.09 8261.08 -8101.08 3519.1 Type 2-D Good test. Stable BU-60s slope 3518.9 3518.77 essentially flat, Spher. Time Func. 5 5 9414.96 8313.55 -8153.55 2968.6 I Type 2-D Good test. No INVEST satge- 2968.86 I 11 Stable BU-RTF 6 5 9440.31 8331.81 -8171.81 2970.61 I Type 2-D Good test. Stable BU-Mod.60s 2969.71 2969.8 slope- Rad.Time Func. 7 5 9558.01 8416.64 -8256.64 3322.2 Type 2-D Good test. stable BU-Mod. 60s 3321.28 3321.84 slope Spher. Time Func. 8 15 9824.07 8608.75 -8448.75 1985.66 I Type 2-D Good test Low 60s slope - 1983.99 1985.48 Radial Time func I 9 5 9846.94 8625.24 -8465.24 2003.19 I Type 2-D Good test. Moderate 60s slope- 12000.56 2003.12 iiiiiiiiiii Spher. Time Fun c I I I I I I I I I I M-11 4 I I Schlumberger Test Point Table IFile Drawdown Mud Mud FPWD Spherical Homer 60 s Time& Pretest Pretest Pretest No. Mobility Before After Pressure Mobility Mobility Slope Date Volume Time Flowrate Temp. Variance I and/cp psia psia psia and/cp md.ft/cp psia/min cc s cc/s DEGF 1 4.8 4118.98 4116.63 0.43 0.15 25-Nov-201 5.76 5.81 0.99 149.81 0174440 1 I 2 24.62 I4117.33 4117.86 0.37 0.14 25-Nov-201 7.5 7.5 1 148.62 0 18:06:07 3 10.32 14339.53 4336.83 0.57 16.37 -.02 26-Nov-201 7.61 7.69 0.99 140.86 - _ 0 22:33:03 I 4 3.84 4369.69 4356.44 0.56 6.91 -.01 27-Nov-201 7.71 7.69 1 144.36 0 01:09:56 I 5 267.08 14389.6 4395.3 0.41 293.84 0.29 27-Nov-201 1016 42 16.19 62.79 146.64 0044654 6 1855.5 I 4392.28 4407.28 0.39 816.38 0.79 27-Nov-201 1024.27 7.44 137.72 145.76 0 05:06:57 I 7 2.81 I 4460.88 4468.19 0.5 3.1 0.69 27-Nov-201 10.22 17.31 0.59 149.76 00814:19 i 8 17.69 14558.14 4550.23 0.32 8.18 0.13 27-Nov-201 15.16 15.19 1 152.19 I 0160841 0.67 9 504.07 4551.65 4553.55 0.33 38.07 27-Nov-201 1016 91 15.13 67.23 152.24 0172835 I I I I I I I I I I M-11 5 Schlumberger Test Point Summary Table Test Types Quantity Type2- D 9 ' TOTAL 9 Gauges AQAP 9 Runs Color 5 9 Formation Pressure Quality: Color 0(no pressure)-10(best) 10 9 Drawdown Mobility Quality: Color 0(no pressure)- 10(best) 10 IF 9 1 1 I 1 M-11 F I Schlumberger Header I ICOMPANY: Chevron Alaska 1 WELL: M-11 FIELD: McArthur River Field BOROUGH: Kenai STATE: Alaska IStethoScope I Schlumberger Bit Run 5 Formation Pressures While Drilling I LL Y Elev: K.B.0 ft Etc a G.L. 185 ft a .5 o D.F. 160 ft 2 2 E 70 Permanent Datum: Sea Level Elev:0 ft I J Log Measured From: DF 160ft above Perm. Datum Drilling Measured From: DF O T I o o . STATE: Max Deviation Latitude Longitude ¢ g ,I m E m LL 3 3 8 UNITED STATES O 60 151 Logging Date 11/25/2010 Run Number 5 I Depth Driller 0 ft Schlumberger Depth 10290 ft Bottom Log Interval 0 ft Lo• Interval 0ftITo. Casing Drilling Size @ Depth 9.63 in 6615 ft Casing Schlumberger 0 ft Bit Size 8.5 in I T •e Fluid in Hole Gel Chem Densit Viscosit 9.2 lb/gal 47 cg Mud Fluid Loss PH 0 ml 9.5 Source of Sample Active tank I RM @ Measured Temperature 0.22 @ 69 DEGF @ RMF @ Measured Tem•erature 0.19 @ 69 DEGF @ RMC @ Measured Tern gerature 0 @ 0 DEGF @ Source RMF Source RMC Pressed IRM @ MR RMF @ MRT 0 159.8 D: 0 159.8 D---_ Maximum Recorded Temperatures 0 DEGF 0 DEGF 0 DEGF Circulation Slog ped Time I Log per On Bottom Time Unit Number Location OLU-K OFFSHORE Recorded By M.Zaripov Witnessed B S.Hauck I I Ill M-11 7 1 1 Hookload Plot It has been learned on previous jobs to reduce lost seals and packer damage, before every depth set to observe the up weight and down weight and set the tool in the mid-range, known as the rotating weight, irrespective of rig type. ' Below is shown the test weights for this job, between the up and down weights: 0 50 100 150Hoo 21000 ,K250 300 350 400 8000.00 8200.00 ' 8400.00 8600.00 8800.00 09000.00 9200.007e#''' ro 9400.00 9600.00 .30 t ) 1 9800.00 , 10000.00 I 1 Test Weight m► 1 DN Weight Rot Weight ' UP Weight 1 1 8 I Schlumberger Inclinometry Tables I M-11 Source :Supplied Survey table I MD TVD 1 Devi ' Azimuth ' North East Departur Departur Dogleg e I e Severity Azimuth ft ft Deg Deg ft ft ft Deg Deg/100f I 0.00 0.00 0.00 0.00 0.00 -0.1 0.00 _0.00 264.71 264.71 0.08 221.49 -0.14 -0.12 0.18 220.60 343.27 343.27 0.45 180.89 -0.49 -0.16 0.52 198.08 I 427.97 427.96 0.86 187.94 -1.45 -0.26 1.47 190.17 0.48 487.53 487.52 0.33 19.75 -1.73 -0.26 1.75 188.55 0.89 521.31 521.30 0.75 14.71 -1.43 -0.17 1.44 186.78 1.24 554.75 554.74 1.07 16.67 -0.92 -0.03 0.92 181.87 0.96 I 582.53 582.51 0.71 20.61 -0.51 0.11 0.52 167.83 1.30 610.94 610.92 0.45 12.50 -0.23 0.19 0.30 140.44 0.92 640.65 640.63 0.29 17.30 -0.05 0.24 0.25 101.77 0.54 670.81 670.79 0.02 178.05 0.02 0.27 0.27 85.76 0.90 I 701.06 701.04 0.28 292.74 0.04 0.20 0.20 78.69 0.86 731.73 731.71 0.50 305.73 0.15 0.02 0.15 7.59 0.72 763.71 763.69 0.70 290.00 0.30 -0.28 0.41 316.97 0.63 795.91 795.88 1.08 271.80 0.38 -0.77 0.86 296.27 1.18 I 826.02 825.98 1.73 273.03 0.41 -1.50 1.56 285.29 2.16 855.39 855.33 2.55 263.48 0.36 -2.59 2.61 277.91 2.79 890.63 890.52 3.56 267.80 0.23 -4.47 4.48 272.95 2.87 I 922.29 922.11 4.30 272.08 0.23 -6.64 6.64 271.98 2.34 952.13 951.85 4.99 274.90 0.38 -9.05 9.06 272.40 2.31 985.53 985.11 5.53 276.75 0.70 -12.09 12.11 273.31 1.62 1080.42 1079.27 8.59 282.83 2.81 -23.54 23.71 276.81 3.22 I 1175.34 1172.78 11.24 269.75 4.34 -39.71 39.95 276.24 2.79 1270.21 1265.35 14.00 273.53 5.01 -60.42 60.63 274.74 2.91 1365.06 1356.85 16.52 265.70 4.71 -85.32 85.45 273.16 2.66 1390.11 1380.83 17.18 264.05 4.05 -92.55 92.64 272.51 2.63 I 1432.00 1420.83 17.33 261.13 2.45 -104.87 104.90 271.34 0.36 1456.12 1443.85 17.44 259.47 1.24 -111.97 111.98 270.63 0.46 1551.01 1534.44 17.27 250.60 -6.04 -139.24 139.37 267.52 0.18 I 1645.75 1624.84 17.66 239.30 -18.05 -164.87 165.86 263.75 0.41 1740.54 1714.74 19.34 230.68 -35.34 -189.38 192.65 259.43 1.77 1835.38 1803.61 21.58 223.41 -57.97 -213.53 221.26 254.81 2.36 1930.24 1891.38 23.07 215.23 -85.83 -236.24 251.35 250.03 1.57 I 2025.07 1978.14 24.59 207.76 -118.48 -256.16 282.23 245.18 1.60 2119.76 2063.77 25.99 201.71 -155.20 -273.01 314.04 240.38 1.48 2213.67 2147.55 27.73 198.44 -195.05 -287.54 347.45 235.85 1.85 2309.41 2231.54 29.64 195.67 -238.98 -300.98 384.32 231.55 1.99 I 2404.30 2313.10 31.81 193.89 -285.85 -313.32 424.12 227.62 2.29 2499.22 2393.51 32.40 193.63 -334.85 -325.32 466.86 224.17 0.62 2594.08 2473.59 32.43 193.09 -384.33 -337.07 511.20 221.25 0.03 2688.98 2553.73 32.34 194.33 -433.70 -349.11 556.75 218.83 0.09 I 2783.85 2634.01 32.05 194.23 -482.69 -361.58 603.10 216.84 0.31 2878.66 2714.83 31.00 194.08 -530.76 -373.71 649.13 215.15 1.11 2973.53 2796.99 29.00 191.35 -577.01 -384.18 693.21 213.66 2.11 I 3068.37 2880.59 27.35 3163.06 2965.14 26.15 189.21 -621.06 -392.19 734.53 212.27 1.74 189.55 -663.11 -399.13 773.96 211.04 1.27 3257.75 3050.62 24.82 188.68 -703.33 -405.59 811.90 209.97 1.40 3352.52 3137.10 23.45 186.84 -741.72 -410.84 847.90 208.98 1.45 I 3447.28 3224.63 21.61 184.64 -777.84 -414.50 881.39 208.05 1.94 3541.73 3313.11 19.36 180.69 -810.83 -416.09 911.36 207.17 2.38 3636.52 3403.15 17.04 177.30 -840.42 -415.63 937.58 206.31 2.45 3731.42 3494.43 14.73 171.73 -866.25 -413.24 959.77 205.50 2.43 I 3826.22 3586.64 12.05 165.64 -887.77 -409.05 977.48 204.74 2.83 3921.05 3679.74 9.88 160.06 -905.01 -403.82 991.02 204.05 2.29 I M-11 9 Schlumberger I Inclinometry Tables 4015.92 3773.27 9.48 146.51 -919.18 -396.73 1001.14 203.35 0.42 I 4110.75 3866.85 9.27 131.77 -930.78 -386.72 1007.92 202.56 0.22 4205.67 3960.50 9.58 118.34 -939.63 -374.07 1011.35 201.71 0.33 4300.43 4053.96 9.50 102.88 -945.11 -359.50 1011.17 200.83 0.08 I 4395.24 4147.47 9.59 89.43 -946.78 -343.98 1007.33 199.97 0.09 4490.04 4241.07 8.78 73.39 -944.63 -329.14 1000.33 199.21 0.85 4584.83 4334.78 8.67 56.44 -938.61 -316.26 990.46 198.62 0.12 I 4674.78 4423.68 8.94 41.32 -929.61 -305.99 978.67 198.22 0.30 4769.67 4517.32 9.69 35.49 -917.57 -296.49 964.28 197.91 0.79 4864.43 4610.49 11.32 35.66 -903.52 -286.43 947.83 197.59 1.72 4958.64 4702.84 11.52 35.56 -888.36 -275.57 930.12 197.23 0.21 I 5053.44 4795.71 11.59 34.57 -872.82 -264.66 912.06 196.87 0.07 5148.25 4888.60 11.56 34.82 -857.17 -253.84 893.97 196.50 0.03 5233.10 4971.74 11.45 34.37 -843.24 -244.23 877.90 196.15 0.13 5337.90 5074.43 11.58 33.47 -825.88 -232.55 858.00 195.73 0.12 I 5432.90 5167.50 11.55 33.05 -809.96 -222.11 839.86 195.33 0.03 5527.80 5260.37 12.23 33.35 -793.60 -211.40 821.27 194.92 0.72 5622.78 5352.75 14.62 31.26 -774.95 -199.65 800.25 194.45 2.52 5717.62 5443.96 17.14 30.66 -752.69 -186.31 775.41 193.90 2.66 I 5812.58 5534.19 19.18 33.30 -727.61 -170.61 747.34 193.20 2.15 5907.03 5622.82 21.24 36.24 -700.84 -151.97 717.13 192.23 2.18 6002.42 5711.00 23.59 38.27 -671.92 -129.93 684.37 190.94 2.46 6097.32 5797.28 25.62 40.96 -641.51 -104.72 650.00 189.27 2.14 6192.10 5882.01 27.63 43.65 -610.13 -76.11 614.86 187.11 2.12 6286.92 5965.19 29.73 43.13 -577.06 -44.86 578.80 184.45 2.21 6381.83 6046.57 32.18 43.80 -541.63 -11.27 541.75 181.19 2.58 I 6466.19 6117.23 34.04 44.11 -508.46 20.72 508.88 177.67 2.20 6567.35 6199.99 36.16 43.89 -466.62 61.12 470.61 172.54 2.10 6618.00 6240.70 36.88 43.92 -444.91 82.02 452.41 169.55 1.42 6645.95 6263.00 37.28 43.93 -432.77 93.71 442.80 167.78 1.43 I 6740.80 6338.60 37.01 42.86 -391.15 133.06 413.16 161.21 0.28 6835.64 6414.33 37.03 41.62 -348.88 171.44 388.73 153.83 0.02 6930.49 6489.96 37.21 39.87 -305.52 208.80 370.05 145.65 0.19 I 7025.40 6565.60 37.12 37.11 -260.65 244.48 357.36 136.83 0.09 7120.24 6640.36 38.85 33.25 -212.94 278.06 350.23 127.45 1.82 7215.09 6713.68 39.90 29.88 -161.68 309.53 349.21 117.58 1.11 7309.81 6785.70 41.12 27.75 -107.77 339.17 355.88 107.63 1.29 I 7404.71 6856.59 42.21 27.59 -51.90 368.46 372.10 98.02 1.15 7499.60 6926.30 43.24 28.13 5.02 398.55 398.58 89.28 1.09 7594.52 6995.12 43.82 26.70 63.05 428.65 433.26 81.63 0.61 7689.39 7063.53 43.89 25.15 122.16 457.38 473.41 75.05 0.07 I 7784.24 7131.94 43.80 24.27 181.85 484.85 517.83 69.44 0.09 7879.06 7200.46 43.65 23.72 241.72 511.50 565.74 64.71 0.16 7972.61 7268.13 43.69 23.07 301.01 537.15 615.74 60.73 0.04 8068.65 7337.67 43.54 24.56 361.61 563.90 669.88 57.33 0.16 I 8163.37 7406.40 43.42 25.41 420.69 591.42 725.78 54.57 0.13 8258.24 7475.22 43.57 25.14 479.74 619.30 783.38 52.24 0.16 8352.97 7543.89 43.51 26.38 538.51 647.66 842.29 50.26 0.06 8447.78 7612.70 43.42 26.37 596.94 676.64 902.32 48.58 0.09 8542.64 7681.53 43.55 26.57 655.37 705.73 963.10 47.12 0.14 8637.44 7750.34 43.37 26.73 713.65 734.98 1024.45 45.84 0.19 8732.29 7819.25 43.43 26.60 771.89 764.23 1086.21 44.71 0.06 I 1 8827.22 7888.19 43.44 26.41 830.30 793.36 1148.40 43.70 0.01 8922.10 7957.14 43.34 27.18 888.48 822.74 1210.91 42.80 0.11 9016.99 8026.11 43.41 26.60 946.60 852.21 1273.70 42.00 0.07 9111.89 8095.03 43.45 26.47 1004.97 881.36 1336.70 41.25 0.04 I 9206.61 8163.56 43.86 26.07 1063.60 910.30 1399.96 40.56 0.43 9301.36 8231.79 44.01 24.92 1122.94 938.59 1463.54 39.89 0.16 9396.22 8300.06 43.93 24.37 1182.80 966.06 1527.18 39.24 0.08 9491.00 8368.35 43.89 24.50 1242.65 993.25 1590.83 38.64 0.04 I 9585.74 8436.67 43.81 24.40 1302.39 1020.41 1654.53 38.08 0.08 M-11 10 I Schlumberger Inclinometry Tables 9680.52 8505.16 43.65 24.82 1361.96 1047.70 1718.32 37.57 0.17 9775.50 8573.75 43.88 23.20 1421.97 1074.42 1782.24 37.07 0.24 9870.35 8642.14 43.85 23.57 1482.30 1100.51 1846.17 36.59 0.03 9965.12 8710.40 44.00 23.61 1542.55 1126.82 1910.28 36.15 0.16 10060.02 8778.75 43.85 22.99 1603.01 1152.86 1974.52 35.72 0.16 10154.81 8847.26 43.59 24.23 1663.04 1179.10 2038.62 35.34 0.27 10186.00 8869.83 43.66 24.26 1682.66 1187.93 2059.74 35.22 0.22 10224.64 8897.77 43.74 24.30 1706.99 1198.91 2085.95 35.08 0.21 10290.00 8944.99 43.74 24.30 1748.18 1217.51 2130.37 34.86 0.00 1 I 1 I i M-11 11 Schlumberger Well Path Plots I Ma• View 2130.36 I I I North - I South (ft) I I -2130.36 I -2130.36 West - East (ft) 2130.36 I Cross Section View I 264.71 I I I TVD (ft) I I I 8944.99 I -2130.36 Departure (ft) Plane = 34.9 - 214.9DEG) 2130.36 M-11 12 I Schlumberger Pressure Depth Plot I FORMATION (AQAP psia) MUD BEFORE 1:1168 ft DRAWDOWN TNPH (pu) ROP5(ft/h) (AQAP psia) MOBILITY(AQAP and/cp) il 0 5000 =_:J TVD (MD) :, 60 0 200 0 / 4000 5000 1 10000 ROBB(g/cm3) ECD(Ibm/gal) MUD AFTER (AQAP 1.65 2.65 9 14 psia) I 5 6 [--° A2 8 °o°o°X0vero°o°o TEMPERATURE (AQAP degf) 4000 5000 A34H(ohm.m) 120 220 GR (gapi) 0.1 1000 I 0 150 0.1P16H(ohm.m) 1000 3I I FII ST 2 1 2 I --_ - . 142 8 8000 _ � 1 ��' (8981.1) ( -14Pnr ...,FL r dr_ I Ai Lid ' ^ 1),,8100 � i (9118.8) f "I � FL -1:S 1 711111M 8200111111r 1.111•11111= 34 _ U (9257.2) vS 4 0 4 Wit 4 -. L 8300 -_ I M 5 Q 5 (9396.1) . i Arr k 8400 eI, Ti' -. - - N/ 0 7 (0 7 (9534.9) • 7 - . E 3' i , 1f a - • 8500 - — (9673.4) G 1ST I GO4s . `! ! e � 8 c.::13 (981soo19) 4 1 n ate"'.-_ I M-11 13 Schlumberger XY MUD Before vs MUD After 4570.00 i • 061 Mud Pressure After(psia) 04 ' 3 1 1 1 4110.00 4110.00 Mud Pressure Before(psia) 4570.00 M-11 14 I I 1.0 03 w T OM N. N. I C 6 CD O U r U I a) Q o._c) D_� 1tn •U) 0 1 U o 0 E 0 0 o_ occ, _ -0 d d 0 u) 8 as I C3 ON na x000000 O)(Ov-co E 00 co C---) QO- y a)IT< 666.E,co(O00rnTM Q NNN COM r r CD C"°V IL H IT¢'NNN M'U'V:7-71000 I — /o O 0 to CD al Ta cn to C C Q C (t)0 a) ^ v a) N N O O m¢m 0 C cC a) m 0"0"0 C C d) V) 7 t0 a) • Lito--il Y O rn U rn co (6 (� -21 N N N fn a I CD CD o o T o C'3 N. 1 M >` C 0fi fn o )) C N E 43 0 3 (0 a_ 3 in 'o_ al I ) m 'DD = J -D = = Q p �� E � o m' w off`^ m w` 2 M ci, T .I C31 03 ,-- II L o M a II I CC II T. n N II CO y 11 4mt MI II O C II CL IL I► I I/ COII 0 1► M CD L 0 'r 1II 1 / O 1► U) 1/ U) ii E 7 ! 4) II ~ N t d is CO`t c0 11: CL Oil ■ o64 I co• I 0008 (e!sd)dVOV-31dnSSkid lVnlOV 000V OMdd 0 0008 (e!sd)OMS S3Hd-3SCISS3FJd 110 03H1O0WS 0 111r.• OOZ (ds30)1VOV-3FJn1VH8dW31 lVnlOV 00OV OMdd 0 N ' co 00 co(q I 0008 (e!sd)dVSV-OHflSSOHd lVnlOV NIVFilS SnIn NNV oco cci O r (80)lOAld-3WnlOn IS313Hd 4Z 0 N �B)S�aanssaad T LL (0 i C.' 0 A+ T W1 0 MD /, Fr ai 4=1 • U U ad d LL 2 a a C.0 I CD ON ra OO a00 CO CO Eop 01 a)mc U 1.5 •p_ CA —M a�FQoioioi.ococTaa�Loco o O. N N N a 0 0 T T 0 0,- LLI—H-<QNNNMVV -.-000 a) 1 a p Co U) c is m C CLL 0 N E I1 I 0 0 a1 O O a) > C 01 �o�o m N m Z• c 5 aGLL22 > > NLLca co mai c-o-occNcnmiam> m �. 0' nn o ca ca 3 3 m m To:cc n2 N I Jo F-H a`) a� �CCQ-0-0aa o_co N co 0 � (% c% n ( MFd °� ` ` -� F - 0L _I00 —oCa cn = O a) QD CO O O r 0 C3 co m E O O 4) o iS o ° E N o I— p' 00 0'' LC) -,— O o'' o 0 r 1 O,, 4t 0 W 0, N p'', I O a E I i= 7 1 CO CO CO i ""O' 0 o c o i 7 N N i -- m I:). 15) 78 N — C R m -Oo a o m co -0 = 5 Q 2 o m w o 12 5 m w 2 0'4Z LE (eisd)dVOV-3d IlSSHd lVl13V JOOV OMdd 69417l ' O'4Z 0 LE (eisd)ONIS S3d3d d- fISS3dd il0 03H100INS 6 S44 OL 00Z (do30)1VOV-3df11Vd3dIN311VfIloV 900V 0^Add 0 0 I -m 017Z1.£ (e!sd)dVSV-3df1SS3dd lVf113V NIVd1S S111f1NNV 6 S44L (co)bOAld-31V-11OA 1S313dd 4Z 0 I u_W CD T CO co 1m co C. E N \ Jo m m cs ancc cam c.) 1 .—.r. to aaaE E nn0 �-a co W . >a NN0_r CO N.V V esCOON y O.O- > a)Ia O •Ioo /o v r-- f/) C .= C up C N cU ,i 1 11 = _ C 4) a) o �'^ = Nom..- ^U �� 0 Cl) N la CO Q N 0 C u N L C U U w a)m C'C D u d c.�2 2 ] > 02 0 LL ifs CO �. " nn o m m 3 3 al cc O I zH a� m �cccr$ca a°aa fl-�c-m ..� c� F-1-dC7L__1_100.e.e1-Cl_coO ' To ° u) $' cu O 1 u 0 u O ~ o C7 rM o O /W/ CO 4 IN. _ t• C > r 0 N C N 0) 0 3• io v 3 !n 'o d =' N m o a g o a 2, x 1 N c is _ - 3 � � 3 � � � O \ E �o a) w o m w MOI o CO 0 M Ln • 11 of I1 1 Li- " — 0 N41 N N 11 I ^ 11 0 4-• C 11 Om �.L 11 I /1 1 O 1' N I— E 11 11 0 o 0 0 (/) - o i 11 1 11 0) (/) U 11 d Cl) 41 i Cl) ii c) co n (O N los N I aCD L as1os N 1 0008 (e!sd)dVOV-3HfSS0Hd lVf11OV 000V OMdd 0 v�IYf 0008 (eisd)OW3H S S3Hd- fSSHd 0110 03H100WS O0 Lf) I 00Z (d°J3O)1VOV-3Hf11VH3dW311tll1OV OOOV OMdd 0 CO N CO NN r 0008 (eisd)dVSV 3HIlSS3Hd 1Vf11OV NIVHIS Sf1lf1NNV 0 I� N (CO)10nld-3Wfll0A 1S313Hd Ile 0 N (B(s%eJnsseJd N W T C) C. CO CLI coI V 4 mo u 0 (6 as ca a-c-f0 a) o r-- aaa� E QQw\-a m I E E p 0CV LO LO r CV nNN COODN as CA rf &IQMMM V ��wO U�M d >.U7C31?IQI c\iv77TEv LLI-I-Q CV NCV NCV V V �r00 o N i Q O rr N > c c co u G.LL-,i N .LL-. N Y>.„2 I N N=-- 2a�0_E r.U 0r u y > c00m dMI O C D o_"i-t2 2 > > N a)LL a m 4. ma) c-o-occC0 ) (0ao> a) nn o (c (a 3 3 24 2w 2cc o -c- 1— o i g.R.. af0cc cc a'OO a_a_ C-N- c al oH-H-d CDLL J_J CD p 22H-d(Od CO CD 0 713 0 1 ti CD .1- 03 03 rr _N• _ (C{ M CO o N ma=y Ei CV N C a V ar c m a c m a r' Cl) 0 3 (I) '0 3 Cl) 0 N 0 m -Oo = 3 -0 = c -0 3 -0 3 -o O E o m w` o c' w Co ,r H ■ r>44 ■ 1).< ■■ In 0 In CO r�—Ma 0 cT rr ,r IN CCII O c II --jill o_ =-- .7_- 1 u) III ) ' y o co a IJil 111 0 6'Zl6Z (sed)dVOV-3Hf1SS]1dd ltlnlOV 000V OMdd L'6SI7Z ' l6Z (elsd)OMS3Hd-3HfSS3Hd TIO a3HIOOWS L'6S4OZ - 11111 -7-MIIIIIIIII LO 00Z ( o30)_LVOV-3Hn1VH3dW311VnlOV OOOV OMdd 0 co CV CO -- NN I 6 ZC6Z (elsd)dVSV-3HfSS3Hd-1Vn LOV NIVHt IS Sn1nNNV '6SbZ ^ r N r CV (EO)lOnld 3Wn10A 1S313Hd 4Z 0 N (EIs )ainssei CV N I w CD O', I CD C m O U Tr 0 E o ) aca.c am 111 moo agcy E aari N� c Q N N a N 00) aM co co co U n n C FQ MM�•7 0 (\ LL 0_ TInQ�� ��0C7CM770NO Lc) 0) I / LLH F-Q MM.(77;5 -TrTrro 'O E _a c c it N Q c ii ��� alo � I o E >c��m<OcO o .(T, N •:r o o ti d Z o__=__LI2 2 > > 0 it fC Z N 4) c-0-0 c c C0 M 7 fC a)> >, as o <o m 3 3 2 2 mCC a� a) - HF a) c rocccccc-oo-o00_0_ aN o y I- -- 13cr)3E i,v, roro>jEmN2 UJ M CO O >, NN .= I co C M N r R C C U 0 a � o r a 03 d$ 0 0 v0iv - maa _ v0 ' 0Co — 7 ti -0 '_= c 3 v 12 E ' ` a E Momwocw2 ~ ■ � ■ 1><1 ■ ■ N I O —w 1.0 0, T V E T 3 G C 01,1171111 I CC CI u a) I I- 4- G 1111 LriL:13 I t. 1It c) ` o D 0)ow- co41) III ,- 2 ____,- il _E ED_ = r iii :CL asCI I t III I 0008 (eisd)dVOV-3Hf1SSOHd lVf LOV 000V GMdd 0 p�ppg (eisd)OWS S3Hd-3Hf1SS3Hd 110 03HlOOWS 00 110. 110 0 ou M CU 000 (d030)1VOV-o dn1vH3dI311vn1ov 900V aMdd 0 N- a co al.'s) I 0008 (eisd)dVSV-3Hf1SS3Hd 1Vf110V NIVHIS Sf 1f1NNV 0r` N. (E0)10Ald-3Wn1On 1S313Hd 40 0 M �EIS�aJnS aid M co O ' L O C N CO L ' E I k:..) v y o o o I U 6 C r LL o o a _ O _ N (T m U a maN2 'L d nfn°'�"2m I 4) CA mmt2 vi L Q LL I L mm E 92 H 4..m aa_ a I - m av n g oCn N. 2 ,3,',7,▪app,a m O O O Oa) N a M co oo (eisd)aanssaad 0 -- - 1 0 (CO 0 i CV 0) Cl)in co it ' \� 1 rn w EL C o .-- - L V L i, 0 gai0[ I U _ • 0 0 m0.m Illi Nfir ' _` ',t,�. ' o �� L J A - 1 C 1 m EpTh (10cpU o) _'m io Q) o c CD CC —1.1o EI o ... `b LL- O o 76 iii Io o b o D sangenuaa aanssaad I CD G 0 w N CD o CID © U =1 • U .... (N = +) -a (6 as QUO a-o co I © cL]CL a ) 4.n.0 N (o U coCAI N ra N Cr)Ln O 0.N CO L()), CO CO (0 o N a 7 (OQ Min M cM 0-� LL N- 0 CL >>"00 ,-r 0CMOM70 CV N LLF-F-QMMM(OT 77xO 'O E F- I O s Q C = C C 0 O C Lv a) N N Q U i D — >,>,0 U E a) m p N > C o o m NCO a) (7)-(Tic N a) CL LL 2 7 7 2 aa))I.T. (6 Z O (1) a) C"0 a C C N N 3 a > >, m }'—0 7 L 0 HF m � acccca°asa. al.— = L_ O o5 . 0°oo � � mmaoE�oa) U) F-F-0-0 LL J J O a.e 2 F-CL co 0 N — O a) 1CO CO o 0 o 0 O o 3 C I CO C p© w > mr U m ma a 0 © (1) 0 c 13. (0 a) oa0a ' Qm -o co -0 111 Tr O 0 E g o co w o m w coCo 0 m co • T 3 I CC CO 4t 0 O o H o - • • CO O . LL :._ _ « CL r « F co ca P A CD _ Ui 1 iii Ir- I.- = oN M N — r co as CL a) __--) I til------ - Ir-_, r ; _.... inN 11o m 6'L9EE (e!sd)dVOV-3FJf1SS3FJd 1Vf11OV 000v OMdd 6'900 N —Al 6 SEE (e!sd)OWS S3Hd-3Hf1SS34id 110 03H1OOWS 6'90993 I- 5i- O »J 003 (d030)1V0V-3Hf11VH3dW311Vf11OV 0O0V OMdd 0 N CO CO 7I r n ,- co in ,i: r 6'L8EE (e!sd)dVSV-3Hf1SS9Hd 1Vl1OV NIVHIS SllfNNV 6'9093I (EO)lOAld-3WllOA 1S313Hd 1,Z 0 M ,- co (eisd)aillS aid M• CO LU NI N CID w 0 Li C M L1 I ■ E $ = �_ aa�Jo N -��.n ^ a>ina0 ., .,7) nnwE jm _ I Ca OA N V2 0 - E E O V-CO N N O. (n . CAaHQ/y(A W Oa 8 COOai V-c,--) O.O fa 0- >.(n 0 In In In C)M 7 °O Lo L LLH-HQ co co ol(6 0777 ,-r 'O >, C o CI a CD In 0) a) > Ta C = C N II C LE O QO L.L p, I o 2- >S>2 ' E N m u y N to a(D Q a) O ca c O 2 > C O O N `)m= c c0 0 a_ V22 „ 2o�� 1 11 a)� D N N C'O.„,,, c c N co 7 c0 ... 11 o_0. Ocaa533aNiai CCoa) m I CI 11 r�Na� ia¢¢ °o °°o o aN ° y a) Y O N °oairoa `Oc�'a73i; `a733 � �'o112m m 11 H Cl) C_ 11 N COIL 11 O W 11 0 II 11 O I _ 1' O °n CO 11 CO I WA, 11 > CI r C c U e ' ' m 20- a) o 3 cnn g 3 in V o m 0 = 0 o a a Q -0 3 a 3 -0 O _ 1 \ E o m w 6 21 w` 111 (Nil co N in 0 ^ • o cv CC C DrLIIRIF3-11 11 T .N 11 CO N \ m y u O C a LL " co C I O 11 M 11 U oo Q) ° U) y O• (/) 11 E 0 Cl) 11 = ■ 4) 4) 00 07 N CL o 11 a O 11 (h I a 0 11 u w . O (O 0008 (e!sd)dVOV-3kifSS8Nd 1Vf11OV 000V OMdd 0 •,' I 0 0 (elsd)OAS Said-3Hf1SS3Hd 110 03H1OOAS 00080 ns, 0) V9 c0 00Z (d000)lVOV-alrlIVId3dV1311V1110V 000V OMdd 0 O 0 0 0 0 OM CO ct O co ON 0008 (elsd)dVSV-3Hf1SS3Hd 1VfI3V NIVUIS SfllflNNV 0 co M N N N (eia)ainsseid (EO)lOAld-3Af11OA IS313Hd 4Z 0 I I 0 M C N 123 CM CCD .A,:,. i/#f'gOglll = l> CO oLI U II r Eai _ o ~ w Tti 0 ro. 8- I 1TzU • az maao v/J .AAtGN ct //a/� IVJ �_ ' . .. U .a=0 as-o + sgom o to f— o m a V t I T c i J W 10 6 O O N oNo(eisd)ajnsseid N I I co 0 I N co Lo C m C 4* a �.1 O. 4�yts7 mi LI t =a. N N a T o O O U ��CSsS1,tliil■■ cco i E. E.0 c LI O i — - )-1 til ' 1 a)- LE CC r c6 L.L co a) 1111 d o senRenuaa aanssaid LL ..:1- I L w CV 03 a L coZL1 .111 Tr o E LL. u im N u. n n�oE o m v p�: m -c u (0pNNa7C) N- E covco y (' a Cl) VD 11 3 aIQaimaDv V aiai co.cg aco m o_ >,c0C3u7)u7)in co °D co4oou? LL I—I—a co co co(6 c6 Tr 7 .-.- .o >, 11 m I aa) 11m Ts > ax C a m LL a1 Q m -1/ ii2 I 7^ ��-2 N p j_a) y N o y a� ai��mQ o o m 0 I 11 N C o o d m= C.12 (0 d-=, 22 7- 7 ii2 m `as ng 7mN> 11 as o m coo 3 3 ami w%CC aa) m CI HHY aixcr- - d-d aaa))CO N a H H a c7 LL_J_J CD C]2 2 N d(o a 11 V7 o CO 11 0 I r 11 CO ( N co 11 = N Q rC C 0 l0 C la U 0 C.0c CO m a 11 d) `0 3 u) a 3 v) '0 d O ? m a m aNm 'O 11 4) Vm m aa) c c O 0 E omw omwm _ csi o,qh 11 I CO O o o DJ 1 /2•111M 11 In11 3 CD 11 CC 11 11 it 11 y11 a) 8E_ 4.... 11 Niii I 0 a N -_ ! ! iIII )o = 0 (LI)) - A Lo m I as co li- 111 L'94LE (eisd)dVOV-3Hf1SS38d 1Vl1OV 000V OMdd 9'E91Z N I 0 LL 94LE (eisd)OWS S2Hd-3HfSS3Hd 110 O3H1O0AS 9 E912 __ LU OOZ (d090)1VOtl Ski f11VHdW 3311Vf11OV 0OOv OMdd 0 N a) co N- (o u)N COM to COM L"94LE (eisd)dVSV-3Hf1SS3Hd 1Vl1OV Nit/HIS SllfNNV 9'E91Z (grs OJf CO M (EO)1OAld-3 011110 1S3131dd I4Z 0 w CISN I L W oCDCIDU coMI N O \Or 111 2 as N a t0 ca 0' E _ ^od 0- nco o aa0C)�.0 ill I VJ is COW OC7 Up-p- Cy UQco co4oi�ri(4°^'a - 0. 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Browne Jr. — Sr. Logging Geologist Tollef Winslow — Logging Geologist CANRIG (,\'- /� .,(,\'- -SD ���� (' o Chevron IWO TRADING BAY UNIT M-11 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW 3 1.1. EQUIPMENT SUMMARY 3 1.2. PERSONNEL 3 2. GENERAL WELL DETAILS 4 2.1. OBJECTIVES 4 2.2. WELL RESUME 4 2.3. HOLE DATA 4 3. GEOLOGICAL DATA 5 3.1. WELL LITHOLOGY 5 3.2. FORMATION /ZONE MARKER TOPS 20 3.3. ZONE SUMMARIES 26 3.4. SAMPLING PROGRAM AND DSITRIBUTION 79 4. DRILLING DATA 80 4.1. DAILY ACTIVITY SUMMARY 80 4.2. SURVEY DATA 84 4.3. MUD RECORD 89 4.4. BIT RECORD 91 Enclosures: 2"/100' Formation Log (MD/TVD) 2"/100' Drilling Dynamics Log (MD/TVD) 2"/100' LWD Combo Lithology Log (MD/TVD) 2"/100' Gas Ratio Log (MD/TVD) Final Data CD 2 CANRIG 1 MUDLOGGING EQUIPMENT AND CREW 1.1. EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Comments Downtime Electric Driven QGM Gas Trap Mounted In Possum Belly; FID Total Ditch Gas Hydrocarbon Analyzer And 0 Chromatograph Rate of Penetration (ROP) Primary Draw works Belt Driven 0 Encoder On Drum Shaft(Canrig) Pump stroke counter Externally Mounted Magnetic 0 Proximity Sensor(Canrig) Hookload/Weight on bit(WOB) Hydraulic Pressure Transducer 0 (Canrig) Drill string torque Varco Analog Feed 0 Top drive rotary(RPM) Varco Analog Feed 0 Standpipe Pressure Solid State Pressure Transducer 0 Casing Pressure Solid State Pressure Transducer 0 Mud flow in/out(MFI/MFO) MFI Derived From SPM/MFO From 0 Flow Paddle(Canrig) Pit volumes Radar Pit Probes 0 Driller's work station Explosion Proof Touch Screen 0 (Canrig) Company man's work station Rigwatch (Canrig) 0 Toolpusher's work station Rigwatch (Canrig) 0 Geologist's work station Chevron 0 Pit's work station RigWatch (Canrig) 0 1.2. PERSONNEL Unit Number and Type: ML004 Arctic Steel Mudloggers Years Days Technician Days Sample Catchers Days Lees F. Browne Jr. 30 33 Steve Forrest 2 Zachary Mester 21 Tollef Winslow 3 36 Howard Lamp 4 Josh Michaud 21 Allen Williams 2 CANRIG Chevron 1111011 TRADING BAY UNIT M-11 2. GENERAL WELL DETAILS 2.1. OBJECTIVES M-11 is a grass roots development well drilled from the Steelhead Platform (Leg A-1, Slot 12) targeting secondary depleted shallow Grayling Gas Sands in an area of relatively few well penetrations, southwest of the platform and relatively undepleted deep Grayling Gas Sands primary target sands northeast of the platform. Of particular interest is the deepest Grayling Gas Sand, the G05, whose off set was lost with a collapse of the M-32RD casing. 2.2. WELL RESUME Operator: UNION/CHEVRON Well Name: Trading Bay Unit M-11 Field and Pool: Steelhead Platform Trading Bay Unit State: County Alaska Kenai Borough Company Representatives: Hauck/Loft/Leslie Location: SEC 33, T 9N, R13W, SM Upper Cook Inlet Elevation: — MSL RKB: 160'to MSL RKB to ML 345' Classification: Development Gas API #: 50-733-20-590-00 PERMIT# 210145 AFE#: UWDAK-D-0002-DRL Rig Name / Type: Steelhead Rig#51 Primary Target: Grayling Sands G05, G03, F7, D3B, B8 and B7 Secondary Targets Provide zonal isolation across stacked pay in the GGS Spud Date :-> Finish Date :-> 11/3/10—11/28/10 Total Depth: 10290' Total Depth Formation: Tyonek Mudlogging Company CANRIG DRILLING TECHNOLOGIES MWD Company: SCHLUMBERGER Tools Run: MWD: Survey, Gyro(Surface), Gamma, Resis, Neu Por Bulk Den, Sigma Directional Drilling: SCHLUMBERGER &Stethoscope Drilling Fluids Company: BAROID 2.3. HOLE DATA Hole Maximum Depth T.D. Mud Deviation Shoe Depth Casing F.I.T. Section MD TVD Formation ppgg)t (°inc) MD TVDSS 17.5" 1440' 1428' SZ 9.3 17° 13 3/8" 1420' -1260 13.0 9.25" 6626' 6167' E 9.3 36° 9 5/8" 6615' -6455' 13.0 8.5"+9" 10290' 8944' G5 9.3 43° 7" 5789' -5629' - 4 CANRIG Ch ron TRADING BAY UNIT M-11 3. GEOLOGICAL DATA 3.1. WELL LITHOLOGY Tuffaceous Siltstone(1350'-1410')= pinkish gray; poor induration; lumpy to clumpy; mushy to pasty; clustered to clotted; tacky to slimy; poorly cohesive slight to moderate adhesive; amorphous to sub earthy fracture; sub nodular habit; earthy to greasy luster; silty to clayey to colloidal textures; massive gradational tuffaceous silts, clays, very carbon shale and minor sand. Carbonaceous Shale/Coal (1420'—1430') = mottled brownish black to grayish black; brittle to firm; earthy to sub resinous lusters; matte texture; blocky to sub platy fracture along carbonaceous shale partings; composed of various grades of very carbon shale, sub lignite to lignitic coal; very slight visible gas from coal cuttings. Sand (1490' -1540')=very light gray; clast size range medium lower to fine lower; sub angular to sub round; moderate developed sphericity; moderate sorting; impacted texture; sub mature nature; non to very slight silic cement; unconsolidated; dominant clay matrix; dominant matrix support with possible local grain support; loosely attached; composed of predominantly quartz with various lithic fragments; poor to fair porosity and poor permeability; no show of oil. Sand (1540'-1650')= medium gray to medium light gray; lower fine to upper very fine with occasional medium grains; sub-angular to sub-rounded; spherical to sub-discoidal; moderately to moderately well sorted; unconsolidated sand with some poorly consolidated sandstone;texturally immature; compositionally immature; translucent and milky white quartz with green lithics and black carbonaceous material; no fossils or structure noted; porosity and permeability visually fair; no oil indicators. Tuffaceous Clay(1560'-1620') = light olive gray to olive gray; soft; poorly to moderately indurated; flexible to elastic tenacity; earthy fracture; massive cuttings habit; dull to earthy luster; silty to clayey texture; massive structure; cohesive clay; lumpy to clumpy consistency; very fine orange volcanics imbedded with in clay; no oil. Carbonaceous Shale/Coal (1650'-1680') = brownish black to black; earthy luster; tabular to sub- tabular cuttings habit; planar fracture; mottled texture; laminae to thin structure; no visible gas. Sand (1680'-1710') = light gray to medium gray with brownish tones; lower to upper fine grains with upper medium to lower coarse grains of coal =20%; sand is sub rounded and poor to moderate sorting. Tuffaceous Claystone(1710'-1770')= medium gray to medium light gray with light olive gray sub hues; soft; cohesive and adhesive; lumpy consistency elastic to stiff tenacity; earthy fracture; massive cuttings habit; earthy to dull luster; clayey texture; no oil indicators. Sand (1770'-1800') = light gray to gray; upper fine to upper medium; sub-angular to sub-rounded; sub- discoidal to spherical; moderately sorted; unconsolidated sand, friable sandstone; matrix supported; matrix indeterminate; texturally immature; compositionally immature; translucent quartz with light green lithics and reddish brown to black carbonaceous material; no oil indicators. Tuffaceous Claystone(1800'-1890') = medium gray to medium dark gray with light olive gray sub hues; cohesive and plasticy; soft; lumpy to clumpy consistency; elastic to stiff tenacity; earthy fracture; massive cuttings habit; earth to dull luster; clayey to smooth; massive structure; black carbonaceous material and sand increase as the interval increases; no oil indicators. Tuffaceous Claystone(1890'-1950')= light gray to gray; soft; cohesive clay lumpy to clumpy; elastic to stiff tenacity; earthy fracture; massive cuttings habit; earthy to dull luster; clayey to silty texture; massive 5 CANRIG Chevron 11110111 TRADING BAY UNIT M-11 structure; volcanics and translucent quartz sand reworked into clay; micro laminations of carbonaceous material present; no oil indicators. Sand/Tuffaceous Clay(1950'-2010') = medium gray to light gray; fine to very fine grained with occasional lower medium; sub-angular to sub-rounded; spherical to sub-discoidal; moderately sorted; unconsolidated sand; matrix is volcanic tuff;texturally immature; compositionally immature; translucent quartz with tuffaceous clay; clay contains redish black carbonaceous laminae; pinkish orange volcanics and light green lithics present; no oil indicators. Tuffaceous Claystone(2010'-2085')= light gray to gray; soft; moderately to moderately poor induration; cohesive and adhesive; clumpy to clotted consistency; elastic to stiff tenacity; massive cuttings habit; earthy to dull luster; clayey to silty texture; massive structure; no oil indicators. Carbonaceous Shale/Coal(2085' -2100') = black to blackish brown; hard; moderate to well indurated; planar fracture with some sub-discoidal; resinous luster; massive structure with some laminations in carbonaceous shale; no oil indicators. Sand (2100'-2160')= medium gray to medium light gray; upper fine to lower fine grained; sub-rounded to sub-angular; spherical to sub-discoidal; moderately sorted; unconsolidated sand; matrix indeterminate; texturally immature; compositionally immature; translucent quartz with black carbonaceous material, green lithics and occasional red orange grains; no oil indicators. Tuffaceous Clay(2160' -2220') = light gray to medium gray; soft; cohesive and adhesive; clumpy to lumpy consistency; flexible to elastic tenacity; earthy fracture; massive cuttings habit; waxy to dull luster; clayey to silty texture; massive structure; black carbonaceous material and light brown carbonaceous material mixed with in clay; no oil indicators. Claystone/Tuffaceous Clay(2220' -2280') = light gray to medium light gray; soft; poorly to very poorly indurated; cohesive and adhesive; tacky to punky consistency; stiff to elastic tenacity; earthy fracture; massive cuttings habit; earthy to dull luster; clayey to silty texture; massive structure; no oil. Carbonaceous Shale/Coal (2280' -2310') = black to brownish black with redish brown streaks; moderately hard to hard; planar to irregular to conchoidal fracture depending on grade of carbonaceous material; sub-tabular to irregular cuttings habit; laminated beds of immature redish brown carbonaceous material with sub-mature coal; no oil indicators. Tuffaceous Clay(2310'-2370') = medium gray to light medium gray; cohesive and adhesive; soft; flexible to sectile tenacity; stiff to tacky consistency; earthy fracture; massive cuttings habit; earthy to dull cutting habit;waxy to dull luster; clayey to silty texture; massive structure; black to brownish black carbonaceous material present; no oil indicators. Tuffaceous Clay(2370' -2430') = medium gray to light medium gray; cohesive and adhesive; soft; flexible to sectile tenacity; stiff to tacky consistency; earthy fracture; massive cuttings habit; earthy to dull cutting habit;waxy to dull luster; clayey to silty texture; massive structure; black to brownish black carbonaceous material present; no oil indicators. Tuffaceous Clay(2430' -2490') = medium gray to light medium gray; cohesive and adhesive; soft; flexible to sectile tenacity; stiff to tacky consistency; earthy fracture; massive cuttings habit; earthy to dull cutting habit; waxy to dull luster; clayey to silty texture; massive structure; black to brownish black carbonaceous material present; no oil indicators. Tuffaceous Siltstone(2500' -2550') =very light gray; very poor to poorly indurated; flexible in parts; elastic; lumpy to clumpy; clustered to clotted; some mushy to pasty; tacky to slimy; slightly cohesive; moderate to very adhesive; amorphous to sub earthy fracture; sub nodular to amorphous habit; moderate 6 CANRIG TRADING BAY UNIT M-11 earthy luster; silty to clayey to colloidal texture; massive gradational tuffaceous silts, clays and minor detrital material. Coal/Carbon Shale(2560' -2570') = black mottled; grayish black to brownish black firm becoming brittle in carbon shale; resinous mottled earthy luster; matte texture; blocky to sub planar fracture along carbon shale partings; composed of very carbon shale grading to lignitic coal; slight visible bleeding gas from most coal cuttings. Sand (2580' -2610')=very light gray; clast size range medium upper to fine lower; sub round to sub angular; moderate developed sphericity; moderate to poorly sorted; impacted texture; immature to sub mature nature; no visible silic cement; unconsolidated; clay structured matrix with dominant matrix support with possible local grain support; loosely attached; matrix is very hydrophilic; composed of dominant quartz; fair to poor estimated porosity and poor permeability; no show of oil. Tuffaceous Claystone(2620' -2740')= pinkish gray; very soft to brittle; Slightly sectile; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty in parts; various consistency and tenacity;tacky to slimy; non to slight cohesive; moderate adhesive; amorphous fracture; amorphous to sub nodular habit; moderate earthy luster; silty to clayey to colloidal textures; massive gradational tuffaceous silts, clays and various detrital material. Coal/Carbon Shale(2750' -2790') = black mottled grayish black to brownish black; firm some hard; earthy mottled resinous lusters; matte texture; blocky to sub planar fracture along carbon shale partings; composed of very carbonaceous shale grading to lignitic coal; slight visible bleeding gas from coal cuttings. Tuffaceous Siltstone(2800' -2850') =very light gray; very poor to poorly indurated; slightly sectile; lumpy to clumpy; clustered to clotted; becoming mushy to pasty; tacky to slimy; slightly cohesive; moderate to very adhesive; amorphous fracture; amorphous to sub nodular habit; moderate earthy luster; silty to clayey to colloidal texture; massive gradational tuffaceous silt, clay and very fine sands. Sand (2860' -2940')=very light gray; clast size ranges from coarse lower to fine upper; sub angular to sub round; moderate developed sphericity; moderate sorting; mean size medium grains; impact texture; sub mature nature; no visible silic cement; unconsolidated; clay and silt matrix; matrix support with local grain support in parts; hydrophilic clay loosely attached; composed of quartz with secondary chert and minor various lithic fragments; fair to poor porosity poor permeability; no show of oil. Coal/Carbon Shale(2950' -2970') = black mottled brownish black to grayish black; firm to hard; earthy mottled resinous luster; irregular to sub blocky fracture composed of lignitic coal grading to carbonaceous shale; visible bleeding gas from most coal cuttings. Tuffaceous Claystone(2980' -3030') = pinkish gray; very soft to brittle; slightly sectile; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty in parts; various consistency and tenacity; tacky to slimy; non to slight cohesive; moderate adhesive; amorphous fracture; amorphous to sub nodular habit; moderate earthy luster; silty to clayey to colloidal textures; massive gradational tuffaceous silts, clays and scattered fine to medium sand and sandstone unconsolidated to slightly consolidated with matrix support. Tuffaceous Siltstone(3040' -3090') = pinkish gray;very poor to poorly indurated; brittle in parts; slightly sectile in increased clay content; lumpy to clumpy; clustered to clotted; gelatinous; mushy to pasty in high clay content; slightly cohesive; moderate adhesiveness; amorphous fracture; amorphous to sub nodular habit; earthy luster; silty to clayey to colloidal textures; massive gradational silts, clay and detrital material. 7 CANRIG Chevron 11.11 TRADING BAY UNIT M-11 Sand (3100' -3220') =very light gray; clast size range medium upper to fine lower; sub round; moderate to well developed sphericity; equant grains; fair to poor sorting; polish to impact texture immature to sub mature nature; non to very slight silic cement; clay structured matrix with secondary grain support; matrix is hydrophilic and loose attached; composed of predominantly quartz with minor chert and trace lithic fragments; fair to poor porosity with poor permeability; sand becoming coarse with depth; scattered to minor beds of tuffaceous sandstone to conglomerate sand; grading to sand and tuffaceous siltstone at 3180'to 3220'. Coal (3225' -3240') = black mottled brownish black to grayish black; firm to hard; earthy mottled resinous luster; matte texture; blocky to irregular fractures; composed of sub lignitic to lignitic coal with thin laminations of very carbon clay or shale;visible bleeding out gas from coal cuttings. Sand/Conglomerate sand (3250'—3350') =very light gray to pinkish gray; clast size range coarse upper to medium lower; sub angular to sub round; moderate developed sphericity; poor sorting; chip to impacted textures; sub mature nature; non to very slight silic cement; loose grains with silt and clay structured matrix; loose matrix support with grain support locally; hydrophilic matrix; composed of quartz with secondary chert with trace meta, greenstone and tuff; poor porosity and permeability; no show of oil. Coal/Carbonaceous Clay and Shale(3360' -3400')= black mottled brownish black and grayish black; firm to hard some dense cuttings; earthy mottled resinous lusters; general matte texture; sub blocky to irregular fractures; composed of predominantly lignitic to sub lignitic coal with micro lamination of very carbonaceous clay and some very carbonaceous shale; visible bleeding gas from most coal cuttings. Tuffaceous Silt/Clay(3400'-3480') = medium gray to medium light gray; cohesive and adhesive; soft; tacky and stiff consistency; elastic to stiff tenacity; earthy fracture; massive cuttings habit; dull to waxy luster; clayey to silty texture; indeterminate structure; formation grades between a silty clay and a clayey silty; milky white, fine grained volcanics and black carbonaceous lithics entrained within sample; no oil indicators. Tuffaceous Silt/Clay(3480'-3540') = medium light gray to medium gray; soft; cohesive; lumpy to clumpy consistency; elastic to stiff tenacity; fracture earthy to hackly; massive cuttings habit; waxy to dull luster; silty to clayey texture; indeterminate structure; formation grades between silt and clay; milky white volcanics, quartz sand grains and black carbonaceous material w/in formation; small carbonaceous shale bed around 3525';no oil indicators. Tuffaceous Siltstone(3540'-3600') = light gray to medium light gray; cohesive; lumpy or mushy; tenacity stiff to elastic; earthy fracture; massive cuttings habit; waxy to dull luster; silty to clayey texture; sand sandstone entrained; black carbonaceous material; no oil indicators. Sand/Conglomerate Sand (3610' -3720')= very light gray; clast size range coarse lower to fine upper; sub round; moderate developed sphericity; fair to poor sort; impacted to pitted textures; sub mature nature; no to very weak silic cement; unconsolidated or interbedded with matrix support; scattered local grain support; moderate to abundant hydrophilic clay matrix loosely attached composed of predominantly quartz with secondary chert with minor lithics; fair to poor porosity and permeability; gradation beds of conglomerate sand and sand; grading to increased matrix support by 3690'; no show of oil cut. Coal/Carbonaceous Clay (3730' -3760') = black mottled/striated brownish black; firm to hard; earthy/striated resinous to earthy luster; matte to striated text irregular to blocky fracture; composed of lignitic coal striated with brown micro laminations of very carbonaceous clay; visible bleeding gas from coal cuttings. Tuffaceous Silt(3760'-3820')= light gray to medium gray; soft; cohesive; lumpy to clumpy consistency; stiff to elastic tenacity; earthy fracture; massive cuttings habit;waxy to dull luster; silty to clayey texture; carbonaceous laminae in darker silts; no oil indicators. 8 CANRIG Chevron 111101 TRADING BAY UNIT M-11 Sand/Sandstone(3820'-3850') = light gray to medium light gray with salt and pepper appearance; predominately lower coarse to lower medium; sub-angular to sub-rounded; spherical to discoidal; moderately sorted; sand unconsolidated/well consolidated sandstone; milky white quartz with chert, black carbonaceous material, and green lithics; porosity/permeability visually fair; no oil indicators noted. Carbonaceous Shale/Coal (3850' -3860') =grayish black to black; brittle to crumbly tenacity; planar and conchoidal fracture; sub-tabular cuttings habit; greasy luster; matte texture; laminae structure; no out gassing observed. Tuffaceous Silt/Sand (3860'-3950') = medium gray to medium light gray; soft; cohesive; stiff to tacky consistency; stiff tenacity; earthy fracture; massive cuttings habit; waxy to dull luster; silty to clayey texture; indeterminate structure; loose upper fine, quartz sand grains. Carbonaceous Shale/Coal (3950' -3970') = brownish black to black; brittle tenacity; planar to conchoidal to splintery fracture; tabular, splintery cuttings habit; greasy to waxy luster; matte texture; laminae structure; out gassing bubbles observed. Tuffaceous Silt/Clay(3970'-4050') = medium gray to dark medium gray with olive gray sub tones; soft; cohesive; stiff to tacky consistency; elastic to stiff tenacity; earthy fracture; massive cuttings habit; waxy to dull luster; clayey to silty texture; coal/carbonaceous material present at end of interval; sand < 5% of samples. Tuffaceous Silt/Clay(4050'-4085')= medium gray to dark medium gray; cohesive; soft; consistency stiff to tacky; elastic to stiff tenacity; earthy fracture; massive cuttings habit; dull to waxy luster; clayey to silty texture. Coal/Carbonaceous Shale(4085'-4110') = black to brownish black; moderately to well indurated; moderately hard to hard; brittle to dense tenacity; planar and conchoidal fracture; tabular to sub tabular cutting habit; waxy to dull luster; laminae structure; some out gassing forming small bubbles. Sand (4110'-4170') = medium light gray to light gray with salt and pepper appearance; upper fine to lower medium grained; spherical to sub-discoidal; angular to sub-angular; moderately sorted; unconsolidated sand; translucent and smoky quartz; black carbonaceous material; porosity and permeability visually fair to good; no oil. Tuffaceous Siltstone(4170' -4215')=olive gray to light olive gray; soft; poorly indurated; elastic tenacity; earthy fracture; massive cuttings habit; greasy luster; silty texture; massive structure;volcanic tuff present. Coal/Carbonaceous Shale(4215'-4225') = black to brownish black; moderate to moderately well indurated; planar and conchoidal fracture; tabular cuttings habit; dull to waxy luster; matte texture; out gassing observed. Tuffaceous Siltstone(4225'-4290')= olive gray to light olive gray; soft; poorly indurated; stiff to elastic tenacity; earthy fracture; massive cuttings habit; waxy to earthy luster; silty texture; indeterminate structure;white tuff fragments present; fine black carbonaceous material. Tuffaceous Siltstone(4290' -4235')=olive gray to light olive gray; soft; poorly indurated; stiff to elastic tenacity; earthy fracture; massive cuttings habit;waxy to earthy luster; silty texture; indeterminate structure;white tuff fragments present; fine black carbonaceous material. Carbonaceous Shale/Coal (4345' -4370') = grayish black striated black; firm; earthy micro laminations of resinous luster; matte to striated textures; sub planar fracture along carbon shale partings; composed of very carbon shale and lignitic coal; trace visible bleeds of gas. 9 CANRIG C WI TRADING BAY UNIT M-11 Tuffaceous Siltstone(4380' -4470') = pinkish gray; very poor to poorly indurated; slightly sectile; lumpy to clumpy; clustered to clotted; slightly mushy yo pasty; tackt to slimy; non to slightly adhesive; moderate adhesive; amorphous to sub earthy fracture; amorphous to sub nodular habit; moderate earthy luster; silty to clayey to colloidal texture; massive gradational tuffaceous silts, clays with minor ash. Sand (4480' -4500') =very light gray; clast size range coarse lower to fine upper; moderate developed sphericity; poor to fair sorting; mean size medium; impacted texture; sub mature nature; no visible silic cement; unconsolidated to interbedded with hydrophilic clays; loosely attached; matrix support with some local grain support; composed of predominantly quartz; fair to poor porosity with poor permeability; no oil. Conglomerate Sand (4510' -4570') =very light gray; clast size range pebble to medium lower; sub round to some angular bit impacted grains; general moderate developed sphericity with poor in coarse grains; fair to poor sorting; polished texture; sub mature nature; no visible cement; unconsolidated; grain supported; slight hydrophilic clays; composed of predominantly quartz with secondary chert and various lithic fragments; good porosity; no oil. Conglomerate Sand (4580' -4650') =very light gray; clast size range coarse to medium lower; sub round to some angular bit impacted grains; general moderate developed sphericity with poor in coarse grains; fair to poor sorting; polished texture; sub mature nature; no visible cement; unconsolidated; grain supported; slight hydrophilic clays; composed of predominantly quartz with secondary chert and various lithic fragments; good porosity; no oil. Conglomerate Sand (4660' -4740')=very light gray; clast size ranges from coarse grained to medium lower; sub round; moderate developed sphericity; poor sorting; polished texture; sub mature nature; non to very weak silic cement; predominantly unconsolidated; grain supported with local loosely attached hydrophilic clay matrix; composed of predominantly quartz with secondary chert with trace various lithic fragments; fair to good estimated porosity and permeability; no oil. Coal/Carbonaceous Shale(4750' -4780') = grayish black mottled black; brittle to firm; earthy mottled resinous luster; striated to matte texture; irregular to sub planar fracture along carbon shale partings; composed of lignite and very carbon shale; slight bleeding gas. Conglomerate Sand/Conglomerate(4790' -4830')=very light gray; clast size range coarse upper to fine lower; sub round to sub angular to angular bit impacted fragments with moderate to poorly developed sphericity; poorly sorted; chipped and polished textures; sub mature nature; no visible cement; unconsolidated; grain support with local silt/clay support; slight to moderate hydrophilic clays; no oil. Conglomerate/Conglomerate Sand (4840' -4910')=very light gray to various gray hues; clast size range: pebble to medium upper; angular to sub angular bit impacted fragments; poor developed sphericity; poor sorting; polish to chip textures; immature to sub mature nature; no visible cement; interbedded with clay and as unconsolidated grains; matrix and grain supported locally; hydrophilic clays- loosely attached. Coal/Carbonaceous Clay(4920' -4960')=grayish black mottled grayish brown through micro laminations of carbon clay firm; earthy striated resinous luster; matte to striated textures; composed of lignite and very carbonaceous clay; visible bleeding gas from most cuttings. Tuffaceous Claystone(4970' -5010')= light grayish orange to pinkish gray; soft; brittle; mushy to pasty; slightly cohesive; slight to moderate adhesive; sub earthy fracture; sub nodular habit; greasy to earthy luster; clayey to silty texture; massive beds of reworked silt, clay and various detrital material; sample quality fair to poor with Icm sweeps. 10 CANRIG Chevron IWO TRADING BAY UNIT M-11 Sand (5020' -5070')=very light gray; clast size range medium upper to fine lower; sub round; moderate to well developed sphericity; moderate to poor sorting; polished texture; sub mature nature; no visible cement; moderate to abundant hydrophilic clay matrix loosely attached; dominant matrix support; poor porosity and permeability; composed of quartz with secondary chert and thin laminations of coal and various detrital material; increase matrix clay with depth. Tuffaceous Claystone(5170' -5200') =grayish orange pink; soft; slightly sectile; lumpy to clumpy; clustered to clotted; gelatin; mushy to pasty; tacky to slimy; non to slightly cohesive; slight to moderate adhesive; amorphous fracture; amorphous to sub nodular habit; earthy luster; silty to clayey texture; massive gradational clay and sand; reworked redeposit. Coal/Carbonaceous Shale(5210' -5130') = black mottled grayish brown; firm some hard; resinous laminated earthy lusters; matte to striated textures; irregular fracture; composed of lignitic coal with micro laminations of very carbonaceous shale; some visible bleeding gas. Tuffaceous Siltstone(5140' -5210') = grayish orange pink; poor induration; mushy to pasty; tacky; slightly cohesive; moderate to very adhesive; sub earthy to amorphous fracture; sub nodular habit; earthy luster, silty texture; massive gradational silts, clay and fine grained sand with various detrital material. Coal/Carbonaceous Shale(5220' -5240') = black mottled grayish brown; firm some hard; resinous laminated earthy lusters; matte to striated textures; irregular fracture; composed of lignitic coal with micro laminations of very carbonaceous material. Tuffaceous Siltstone/Claystone(5240' -5360')= medium light gray to light gray; soft; moderately to poorly indurated; elastic tenacity; cohesive; irregular fracture; massive cuttings habit; dull to earthy luster; matte texture; indeterminate structure; sand beds also in interval. Sand (5290'-5330') =gray to medium gray; bimodal sand, upper very coarse to upper coarse and upper medium to lower medium grained; very angular to sub-angular; spherical to discoidal; poorly to very poorly sorted; unconsolidated sand; texturally immature; compositionally immature; milky white and translucent quartz with orangish yellow lithics; porosity and permeability visually good. Carbonaceous Shale(5360' -5395') = black to grayish black; moderately hard to firm friable; moderately to moderately well indurated; brittle to dense tenacity; planar to splintery to conchoidal fracture; tabular to sub-tabular cuttings habit; earthy luster; matte texture; laminae structure. Tuffaceous Siltstone(5395' -5445')= light gray to gray; easily friable; poorly indurated; stiff tenacity; earthy fracture; sub-nodular cuttings habit; dull to earthy luster; silty texture; laminae structure; carbonaceous laminae with in siltstone. Coal (5445' -5465')= black to dark grey with dark brown hues; iron oxide laminae of reddish brown color; hard and brittle; dull to earthy luster; irregular to conchoidal fracture; bleeding gas prevalent in sample grains; lignitic coal with micro laminations. Fine Sand (5465'-5490') = light gray lower to upper fine, sub rounded grains; poor to moderate sorting; unconsolidated; quartz 75%, feldspars, micas, coal. Silty Sand (5490'-5520') = light gray with brownish hues; medium sized clasts with a very fine to silty carbonaceous matrix; angular; with very poor sorting; quartz 60%, feldspar, mica and coal. Coal (5540'-5555') = black to dark gray; mottled; hard and brittle; irregular fracture; bituminous degassing. Sandy Carbonaceous Siltstone(5555'-5610') = light to medium gray; micro-coal interbedded with siltstone; friable; including clasts of quarts&feldspars; very well to well sorted rounded grains. 11 CANRIG Chevirli 1111110 TRADING BAY UNIT M-11 Sand (5610'-5640') = light to medium gray; upper to lower medium grains; fair to well sorted; rounded grains; unconsolidated; grain supported stringers; quartz 80%, coal 15%, feldspar&other. Sand (5640'-5670')= light gray; upper medium to lower coarse grains; fairly sorted; sub angular to sub rounded grains; unconsolidated fragments; grain supported; quartz 85%, coal 5%, feldspars 5%, others 5%. Carbonaceous Siltstone(5670' -5730') = dark gray to light gray; easily friable; crumbly; dull to earthy luster; mushy to pasty; coal micro bedding; coal present in 15% abundance, quartz sand grains 5%, feldspars 5%. Coal (5735'-5745')= black to dark gray with moderate to dark brown hues; hard and brittle; earthy to shiny luster; mottled with irregular fracture, readily bleeding gas, bituminous. Sand (5745'-5790') = light to medium gray; upper medium to lower coarse grains; angular to sub angular rounding; poor to moderate sorting; generally unconsolidated; grain supported sands; mature; 75+%quartz, 5-10%feldspars, 5%coal, <5% mica, trace sandstone. Sand (5790'-5820')= light to medium gray; upper very fine to lower fine; sub rounded to sub angular; well sorted grains of consistent size; unconsolidated; grain supported; mature; quartz 75%, assorted mafic minerals 5-10%, feldspars 5%. Sand (5820'-5850')= light to medium gray; lower to upper coarse; sub-discoidal; angular to very angular; poorly sorted; very poorly consolidated; matrix supported; immature; quartz 70%feldspars, assorted mafic minerals. Sand (5850'-5880')= medium to dark gray lower to upper medium sized grains; very poor to poor sorting; very poor to unconsolidated; matrix supported with very fine sand grains; immature; quartz 60%, assorted mafic minerals, feldspars, coals, and micas. Coal(5885'-5895') = black to dark gray with dark brown to reddish brown hues; hard and brittle; dull to earthy resinous and laminated; trace sandstone. Sandy Carbonaceous Siltstone(5895'-5935')=dark brown to dark gray; easily dense; silty texture; dull to earthy luster; trace coarse quartz, feldspar, and mafic minerals. Coal (5935' -5945')= black to dark gray; hard and brittle; matte; earthy to resinous luster; irregular to conchoidal fracture; bituminous. Sand (5950'-6000') = light gray; lower medium to upper fine grained; sub angular to sub rounded grains; moderate to well sorted; unconsolidated; matrix supported quartz 70%, feldspars, micas, assorted mafic minerals; sandstone fragments. Conglomerate Sand/Conglomerate(6010' -6050')=very light gray; clast size range very coarse to medium lower; sub angular to sub round; scattered angular bit impacted fragments; poor to moderate developed sphericity; poorly sorted; polished coarse grains to impacted medium grains; sub mature nature; non to weak silic cement; unconsolidated with scattered clusters of medium to coarse grained sandstone; non to slight visible hydrophilic clay matrix; dominant grain support; composed of predominantly quartz with secondary chert and minor dark lithics; fair to good porosity and permeability; no show of oil. 12 CANRIG Chevron WI TRADING BAY UNIT M-11 Coal/Carbonaceous Shale and Carbon Clay(6060' -6150') = brownish black mottled black; brittle to firm; predominantly earthy luster with micro laminations to mottled resinous lusters; matte to striated textures; predominantly sub planar fracture along shale lamination partings; composed of sub lignite to very carbonaceous shale and clay; trace amber and plant fossils; visible bleeds of gas from fresh cuttings; occurs as thin to thick beds with silts and clays. Tuffaceous Siltstone(6160' -6200') =grayish orange pink to pinkish gray; poorly indurated; slightly sectile in clay sections; mushy to pasty; tacky to slimy; non to slightly cohesive; moderate to very adhesive; earthy to amorphous fracture; sub nodular habit; earthy to greasy luster; silty to clayey texture; massive gradational silts and clays interbedded with detrital material. Coal/Carbonaceous Shale(6210' -6240')= black; brittle to firm; predominantly earthy luster with micro laminations to mottled resinous luters; matte to striated textures; predominantly sub planar fracture along shale lamination partings; composed of sub lignite to very carbonaceous shale and clay; trace amber and plant fossils; visible bleeds of gas from fresh cuttings; occurs as thin to thick beds with silts and clays. Tuffaceous Silt(6250' -6350') = pinkish gray to grayish orange pink; poorly indurated; becoming sectile in rich clay beds; mushy to pasty; tacky to slimy; slightly cohesive; moderate to very adhesive; sub earthy fracture; sub nodular habit; earthy luster; silty to clayey texture; massive gradational tuffaceous silts and secondary clays; scattered carbon shale and clay beds. Sand/Conglomerate Sand (6360' -6400') =very light gray; clast size range coarse upper to fine upper; no abundant faction moderate developed sphericity; poorly sorted; impacted medium to polished coarse grains; sub mature nature; non to very weak silic cement; unconsolidated with scattered loosely consolidated clusters with clay matrix; grain supported with secondary local matrix support; composed of quartz with secondary chert and minor lithics; fair porosity and permeability. Tuffaceous Claystone(6410' -6440')= pinkish gray; very soft; lumpy to clumpy clustered to clotted; gelatin; slightly mushy to pasty mostly soupy; very hydrophilic; non to very slightly cohesive; moderate adhesive; amorphous fracture and habit; earthy luster; clay to colloidal texture; interbedded with medium to fine grain sand; matrix support. Conglomerate Sand/Sand (6450' -6520') =very light gray to light gray; clast size very coarse lower to fine upper; angular coarse bit impacted grains to sub round medium; poor to moderate sphericity; abundant factions coarse and medium matrix sands; very poor sorting; chip coarse to impacted medium grains; sub mature nature; non to weak silic cement; unconsolidated to scattered loosely consolidated clusters with hydrophilic matrix; composed of 90% quartz, 10% chert various lithic grains; fair to good porosity; no oil indicators. Carbonaceous Shale/Coal (6520' -6530') = black to grayish black; moderately hard; brittle tenacity; planar and conchoidal fracture; massive cuttings habit; resinous luster; laminae structure. Tuffaceous Siltstone(6530'-6600') = light gray to gray; soft; stiff tenacity earthy fracture; massive cuttings habit; earthy luster; silty texture; massive structure; no oil indicators. Carbonaceous Shale/Coal (6600'-6610')= black to grayish black; moderately hard tenacity brittle; planar and conchoidal fracture; massive cuttings habit; resinous luster; laminae structure. Tuffaceous Claystone(6630'-6700')= medium light gray to light gray with light olive gray sub hues; cohesive and adhesive; soft; lumpy to clumpy consistency; earthy fracture; massive cuttings habit; earthy to dull luster; clayey to silty texture; indeterminate structure; interval grades towards tuffaceous siltstone with translucent to milky white quartz sand grains which are bimodal upper medium to lower medium and upper coarse to lower very coarse, black mafic and yellowish orange lithics; no oil indicators. 13 CANRIG Chevron IWO TRADING BAY UNIT M-11 Conglomerate/Conglomerate Sand (6710' -6790')=very light gray to light gray; clast size range very coarse upper to fine upper; angular coarse bit impacted to sub round medium to fine matrix sands poor to moderate developed sphericity; no abundant size faction; very poorly sorted; chip coarse to impacted sub round medium grains; sub mature nature; partly consolidated with weak silic and calcite cement; dominant grain support very slight hydrophilic matrix clay; fair to good porosity and permeability; appears arenaceous sub greywacke; composed of 90% quartz, 10% chert and various dark lithic fragments; no show of oil fluorescence or oil stain. Tuffaceous Siltstone(6800' -6850')= light gray; poorly indurated with some moderate fragments; slightly sectile; mushy to pasty; slimy; slightly cohesive; moderate adhesive; sub earthy to amorphous fracture; amorphous to sub nodular habit; earthy luster; silty to clayey texture; composed of silts with gradational clay and various detrital material. Carbonaceous Shale/Coal (6860' -6880') =grayish black mottled brownish black; firm; brittle in carbon shale to firm in coals; earthy mottled resinous luster; matte to striated texture; irregular to planar fracture along shale partings; visible bleeding gas from coal cuttings. Tuffaceous Siltstone(6890-6950') =grayish orange; very poor to poor induration; slightly sectile; lumpy to clumpy; clustered to clotted; mushy to pasty; hydrophilic; slightly cohesive; moderate adhesive; amorphous to sub earthy fracture; sub nodular habit; earthy luster; silty to clayey textures; gradational beds of silt and clay; small carbonaceous shale/coal at 6940'. Sand (6960' -7000') =very light gray; clast size range medium upper to fine upper; sub round; moderate to well developed sphericity; moderate sorting; polished texture; sub mature nature; no visible cement; unconsolidated; clay matrix loosely attached; matrix support with secondary local grain support; poor porosity and permeability; compose of>90%quartz; no oil. Carbonaceous Shale/Coal (7010' -7030')=grayish black mottled brownish black; firm; brittle in carbon shale to firm in coals; earthy mottled resinous luster; matte to striated texture; irregular to planar fracture along shale partings; visible bleeding gas from coal cuttings. Conglomerate/Conglomerate Sand (7040' -7150') =very light gray to light gray; clast size range very coarse upper to fine upper; angular to sub angular coarse grains to sub round medium to fine grains; poor to moderate developed sphericity; very poorly sorted; polished coarse grains to impacted medium grains; sub mature nature; non to very weak silic cement; unconsolidated with some weakly consolidated clusters; very slight clay matrix; dominant grain support; arenaceous appearing as a sub graywacke; becoming coarser with depth; good porosity and permeability; composed of 90%quartz, 10%chert with minor dark lithics. no show of oil. Coal/Carbonaceous Shale(7150' -7200') = black to grayish black; firm; resinous; matte texture; sub conchoidal to irregular fracture; composed of lignite to sub bituminous coal; visible bleeding gas from cuttings. Conglomerate Sand/Conglomerate(7210' -7300')=very light gray to light gray; clast size ranges from very coarse upper to medium lower; medium grains becoming coarse grained after 7240'; moderate developed sphericity; very poorly sorted polished and chipped textures; sub mature nature; no visible cement; unconsolidated with slight medium grain consolidated clusters weakly cemented; dominant grain support; no visible matrix material; composed of>90% quartz with secondary chert and trace dark gray lithics (argillite); good porosity and permeability; appears as a clean arenaceous sand; a sub gray wacke in parts. Coal/Carbon Shale(7300' -7310') = black to grayish black; firm; hackly to sub conchoidal fractures; resinous to some earthy luster; lignitic to bituminous coal with very carbon shale laminations; visible bleeding gas larger cuttings. 14 CANRIG Chevron IWO TRADING BAY UNIT M-11 Sand (7310'-7350') = light to medium gray; upper medium to lower coarse; spherical to sub discoidal; sub angular to sub rounded; moderately sorted; unconsolidated; grain supported; quartz 75%, feldspar, mafics, mica, etc. Tuffaceous Claystone( 7350' -7380')= medium to dark gray; poorly inundated; malleable and crumbly; flaky; clayey; earthy to dull; pasty; carbonaceous shales and sands. Silty Sandstone(7380' -7440') = light to medium gray; very coarse grains w/silt matrix; spherical to sub- discoidal; very angular to angular grains; poor to moderate sorting; moderately consolidated; grain supported rock; immature; quartz 70%, feldspars, micas, carbonaceous shale with plant fossils; tight permeability visually. Sand (7440'-7470') = light to medium gray with light pinkish to greenish gray hues; lower medium to upper fine grains; rounded to sub-rounded sub-discoidal grains; well to very well sorted sands; sandstone fragments consolidated while sands unconsolidated; grain supported; quartz 80%, feldspars, argillite, micas; carbonaceous shale fragments with micro interbedded lignitic coal seams; fair permeability visually estimated. Tuffaceous Siltstone (7470' -7500') = pale brown to pale yellowish brown; dense and tough; tabular; clayey and mottled; dull and earthy; adhesive and pliable; interbedded micro coals; carbonaceous shales present. Sand (7500'-7545') = medium to dark gray with light olive gray hues; lower fine to upper very fine;well rounded to rounded grains; spherical to sub-discoidal; unconsolidated; well sorted sands; grain supported; tuffaceous silt matrix; quartz 70%, feldspars, mafics, etc. Tuffaceous Siltstone(7545' -7560')=dark gray with light olive gray hues; malleable; massive; clayey& colloidal; dull and earthy; cohesive to adhesive; mushy to tacky; lower coarse sand grains and carbonaceous shale present. Sand (7560'-7590')= medium to dark gray; lower to upper fine grains; spherical rounded to sub-round; well sorted; unconsolidated; grain supported; quartz 90%, mafics, feldspars; mature. Tuffaceous Siltstone(7590'-7650')= medium dark gray; crumbly and malleable; massive; silty and colloidal; dull and earthy; cohesive; clumpy and clotted; carbonaceous shale interbedded in silt. Sandy Tuffaceous siltstone(7650'-7735')= medium dark gray; dense; massive; clayey to silty; dull & earthy; cohesive pliable and colloidal; mushy and tacky; interbedded with carbonaceous shale; pyrite inclusions. Carbonaceous Shale(7735'-7760') =dark gray with brownish gray to olive gray hues; hard and brittle; well indurated; irregular to conchoidal &splintery in some fracture; scaly: metallic luster; abrasive texture; prevalent degassing and coal present. Conglomerate/Conglomerate Sand (7770' -7880') = light gray to very light gray; clast size ranges from pebble/very coarse to medium lower; angular to sub angular bit impacted coarse grains to sub round medium grained matrix sands; poor to moderate developed sphericity; most grains equant; polish and chipped coarse grains to impacted medium grains; sub mature nature; no visible cement; unconsolidated with no visible matrix material; dominant grain supported; appears arenaceous and as a sub greywacke; good porosity and permeability; composed of 80%quartz, 10% chert, 10% igneous, metamorphic, feldspar, greenstone and various lithic fragments; no show of oil fluorescence or oil cuts. Coal/Carbonaceous Shale(7890' -7900') = black to grayish black; firm; resinous to earthy luster; matte texture; sub conchoidal to irregular to sub planar fracture; composed of very carbon shale and lignitic coals. 15 CANRIG Coven oven kW TRADING BAY UNIT M-11 Conglomerate/Conglomerate Sand (7900' -7920')= continued coarse grain sand and grain support to 7920'. Tuffaceous Claystone(7930' -7950') = pinkish gray; very soft; lumpy to clumpy; clustered to clotted; gelatinous; slight mushiness; very hydrophilic; non to slight cohesiveness and adhesiveness; amorphous fracture and habit; clayey to colloidal textures; thick beds of gradational silts and clays. Tuffaceous Siltstone(7960' -8030') = pinkish gray; poorly indurated; some clustered to clotted; gelatinous; slight mushiness; very hydrophilic; non to slight cohesiveness and adhesiveness; amorphous fracture and habit; clayey to colloidal textures; thick beds of gradational silts and clays. Conglomerate Sand (8040' -8080') =very light gray; clast size coarse upper to fine upper; sub angular to sub round; moderate developed sphericity; very poor sorting; polish, chip and impact texture sub mature nature; non to very weak silic cement; unconsolidated with few weakly consolidated sandstone clusters; dominant grain support; very slight hydrophilic clay matrix; composed of>90% quartz, with secondary chert and various lithic fragments; fair to good porosity and permeability; no oil. Tuffaceous Claystone(8090' -8160') = pinkish gray; very soft; lumpy to clumpy clustered to clotted; gelatinous; mushy to pasty; soupy; hydrophilic; non to very slight cohesive; moderate adhesive; amorphous fracture and habit; earthy luster; clayey to silty to colloidal textures; massive gradational tuffaceous silts and tuffaceous clays with trace ash; coal from 8135 to 8145'composed of lignitic to sub bituminous and very carbonaceous shale and clay at contacts. Tuffaceous Siltstone(8160'-8190') = medium light gray with pinkish to yellowish gray sub hues; non indurated; crumbly; massive gradational tuffaceous clays and silts; silty to clayey; dull and earthy; clumpy to clotted; cohesive; mildly adhesive; micro beds carbon shale Conglomerate/Conglomeratic Sand (8190'-8260')= medium light to pinkish gray with pale yellowish brown sub hues; gravel sized clasts with lower to upper coarse sand matrix; main clasts are rounded to well rounded spherical to sub-discoidal, while matrix is angular to sub-angular; poor sorting overall, matrix is very well sorted; unconsolidated; matrix supported; immature; matrix-quartz 60%, mafics, feldspars, greenstone; sandstone clasts. Carbonaceous Shale(8260' -8280') = brownish black to dark gray in color; hard and brittle; moderate to well induration; bladed cuttings; abrasive and mottled; metallic to dull; lenticular bedding; highly angular quartz grains present. Sand (8280'-8340')= light to medium gray with light olive gray hues; upper fine to lower medium spherical to sub-discoidal rounded to well rounded grains; unconsolidated; matrix is tuffaceous silts; grain supported; mature; quartz 80%, mafics, greenstone, feldspars, micas; angular coarse quartzite present along with non-indurated tuffaceous siltstones. Conglomerate/Conglomeratic Sand (8340' -8420') = medium light to medium gray; clasts of conglomerate are pebble sized; spherical to sub-discoidal rounded to very rounded grains; poorly sorted; unconsolidated; matrix supported conglomerate; matrix is very coarse sand; sub-prismoidal to spherical angular to sub-angular grains; unconsolidated and well sorted matrix; quartz 60%, mafics, greenstone, feldspars, quartzite. Carbonaceous shale(8420' -8440') = dark gray to brownish to greenish black; hard and brittle;well induration; platy and scaly; abrasive and mottled; metallic to polished; lenticular bedding. Sandy Tuffaceous Siltstone(8440'-8510') = light to medium light gray with pinkish to yellowish gray hues; poorly indurated; crumbly; massive habit; silty to gritty; dull and earthy; cohesive, mildly adhesive; 16 CANRIG Chevron NW TRADING BAY UNIT M-11 sand inclusions are sub rounded to sub angular, spherical to sub discoidal well sorted sands; unconsolidated; sand quartz, mafics, feldspars, trace greenstones. Carbonaceous Shale(8510' -8530')= brownish black to olive black; hard and brittle; well induration; scaly and platy; abrasive and mottled; metallic to resinous; lenticular bedding. sand (8530'-8550') medium light gray to medium gray with light olive gray hues; spherical to sub-discoidal; sub-angular to sub-rounded grains; moderate to well sorting; unconsolidated; grain supported; quartz 75%, mafics, feldspars greenstones, micas, etc. Tuffaceous Siltstone(8560' -8630') = light gray; poor to moderate induration; crumbly to crunchy in parts; sub platy to irregular fracture; sub planar habit; earthy luster; silty texture; uniform tuffaceous silt; composed of>80%friable silt with detrital material coal and carbon shale at 8560'. Coal/Carbonaceous Shale(8640' -8660') = black mottled grayish black to brownish black at contacts; brittle in carbon shales to firm some hard in coals; resinous to striated earthy luster; matte to striated textures; irregular to sub planar fractures in carbon shale; composed of micro laminations of carbon shale to lignitic coal; no bleeding gas Tuffaceous Siltstone(8660' -8770')= medium gray to light brownish gray; pale yellowish brown to grayish olives hues; easily friable; very poor induration; crumbly to crunchy; massive; mottled and gritty; dull and earthy; cohesive, mildly adhesive; micro inter-bedding of carbonaceous shale. Carbonaceous Shale(8770' -8780') =grayish to brownish black, mottled; hard and brittle; moderate to well indurated; scalar and platy; abrasive; metallic to resinous; lenticular bedding. Sand (8780'-8825') = medium light gray to medium gray; upper fine to lower medium grains; spherical to sub-discoidal sub-rounded to rounded grains; unconsolidated; grain supported; mature; quartz 85%, mafics, feldspars, greenstones. Carbonaceous Shale(8825'-8840') = brownish to olive gray with dark yellowish brown hues; hard and brittle; moderately induration; platy and scaly; abrasive; metallic to resinous; lenticular bedding; light degassing; plant fossils interbedded Tuffaceous Siltstone(8840' -8905')= medium to medium light gray with light brownish to olive gray hues; easily friable; poor to v. poor induration; crumbly; massive; silty to clayey to gritty; dull and earthy; cohesive mildly adhesive, interbedded carbonaceous micro shales. Carbonaceous Shale(8905'-8920') = medium dark gray to dark gray with brownish to olive gray hues; mottled; hard and brittle; moderate to well induration; scaly to platy; abrasive; metallic to resinous; lenticular beds; degassing present. Sand (8920'-8970')= light to medium light gray with light olive gray to greenish gray hues and tones; lower medium to upper fine sub-rounded to sub-angular spherical to sub-discoidal grains; unconsolidated; grain supported; quartz 80% mafics, feldspar, greenstone. Carbonaceous Shale(8970'-8990') =dark gray to grayish black with olive to brownish gray hues; mottled surface; hard and brittle; moderate to well induration; scaly and platy; abrasive; metalic and resinous; lenticular scaly beds; degassing and plant fossils, Sand (9000' -9070') =very light gray; clast size medium lower to fine lower; sub round; moderate developed equant sphericity; moderate to well sorted; impact texture; mature nature; no visible cement; unconsolidated; appears arenaceous; no visible matrix material; composed of>95% quartz with chert and trace lithics; good porosity and good permeability; no show of oil. 17 CANRIG Chevron IWO TRADING BAY UNIT M-11 Coal/Carbon Shale(9080'—9110') = black mottled grayish black to brownish black at contacts; brittle in carbon shale to firm to hard in coal; earthy mottled resinous luster; hackly to irregular fracture in coal to sub planar in carbon shale; occurs as thin beds; out gassing. Tuffaceous Siltstone/Sand (9120' -9190') = pinkish gray; poor-moderate induration crumbly to crunchy; stiff in parts; some grading to sand; sub earthy fracture; sub nodular habit; dull earthy luster; silty to sandy texture; grading to clean fine to medium sand as lenticular beds; some sandstone grading to siltstone; hydrophilic clays, sand and silts Sand (9200' -9240') =very light gray; clast size medium lower to very fine upper; mean size fine grained; moderate to some well developed sphericity; moderate sorting; impact texture; sub mature to mature nature; no visible cement; unconsolidated; arenaceous; dominant grain support; >95%quartz; good porosity& permeability; no oil. Sand (9250' -9320') =very light gray; clast size range medium lower to fine lower; sub angular to sub round; moderate developed sphericity; equant grains; moderate to well sorted with scattered coarse grains; impact texture; mature nature; non to very weak silic cement; unconsolidated; arenaceous; very slight clay/tuff matrix on scattered consolidated clusters; composed of>95% quartz with minor chert and trace lithic fragments; good porosity and good permeability; no oil indicators. Tuffaceous Siltstone(9330' -9390') = pinkish gray to pale yellowish brown; poor to moderate induration; brittle to stiff; crumbly to crunchy; slight to moderate cohesiveness; slightly adhesive sub earthy fracture; sub nodular habit; dull earthy luster; silty texture; thick gradational beds of tuffaceous silts and tuffaceous clays; scattered carbon shale and minor coal ay 9380'; trace ash. Sand (9410' -9490') =very light gray; clast size medium upper to fine lower scattered coarse grains; becoming coarse with depth; moderate developed sphericity; equant grain size; sub round moderate sorting; impacted texture; no visible cement; unconsolidated; dominant grain support; arenaceous; no visible matrix material; composed of>90% quartz secondary chert, trace lithics; good porosity and permeability; no oil grading to carbon shale/clay minor coal Sand/Tuffaceous Sandstone(9500' -9550')=very light gray to distinct pale yellow orange tuff matrix; clast medium upper to fine lower; moderate sphericity; equant grains; moderate sorting; impact texture sub mature nature; slight to moderate ash fall tuff matrix and cement; pore filling and a lithifying agent; grain support grading to matrix support with depth; composed of>95% quartz with various lithic fragments; fair porosity and fair to poorer permeability with depth; mineral fluorescence; no oil. Sand/Tuffaceous Sandstone(9550' -9590')= light gray with pinkish yellowish gray hues; lower medium to upper fine clasts; spherical to sub-discoidal sub-angular to sub-rounded grains; moderately to well sorted sands; poor to moderate consolidation; tuffaceous matrix and cementing; grain supported sands and sandstones; mature; quartz 95%, mafics, feldspar, greenstone, other lithic fragments; mineral fluorescence; no oil. Carbonaceous Shale/Coal (9590'-9610') = brownish black to brownish gray; hard and brittle;well induration; scaly; abrasive and mottled; resinous to greasy; hydro fissile; micro coal inter-bedding with carbonaceous shale. Sand/Tuffaceous Sandstone(9610'-9630') = medium light to light gray; upper to lower fine grains; rounded to sub rounded spherical clast;well sorted; moderately consolidated; grain support; 90%quartz, mafics,feldspar, greenstone and other lithic fragments. Tuffaceous Siltstone(9630' -9690')= medium gray to light brownish gray; friable; poor to very poor induration; crumbly and stiff; massive; silty to gritty; dull and earthy; cohesive mildly adhesive; mushy; 15% sand. 18 CANRIG C 11110 TRADING BAY UNIT M-11 Carbonaceous Shale/Coal (9690' -9710')= brownish gray to black; hard &brittle; moderate to well induration; flaky; abrasive and mottled; micro-interbedded with coals; degassing present. Sand (9710'-9750')= light medium to medium gray with light olive gray hues; lower medium to upper fine grained; spherical to sub-discoidal sub-rounded to rounded grains; well sorted; unconsolidated; grain supported; mature; tuffaceous cementing, silt matrix; quartz 85%, mafics, feldspars, etc. Tuffaceous Siltstone(9750'-9810') = light brownish gray to medium light gray; friable to firm friable; poor to moderate induration; crumbly to crunchy; silty to gritty to clayey; dull and earthy; cohesive; micro interbedded carbonaceous shale; 10% quartz sand. Sandy Tuffaceous Siltstone(9810'-9910') = medium to medium dark gray with light olive gray to grayish orange pink hues; easily friable to friable; poor to moderately indurated; dense and crumbly; dull and earthy; cohesive and mildly adhesive; micro-inter-bedding with carbonaceous shale grading to sand: lower medium to upper fine; spherical to sub-prismoidal; sub-angular to sub-rounded grains; quartz 80%, mafics, etc. Carbonaceous Shale(9910'-9930')= grayish black to brownish gray, mottled; hard and brittle; moderate to well induration; scaly and bladed; resinous to polished; micro interbedded coals. Sand (9940' -9990')=very light gray; clast size medium upper to fine lower; sub round; moderate developed sphericity moderate sorting; impacted texture; mature nature; non to very weak silic cement; unconsolidated; no visible matrix material; dominant grain support; composed of>90%quartz; 80%+dull to moderate yellow even sample fluorescence; scattered very light brown oil stain; weak slow light blue green oil cut slow streaming opaque to moderate milky blue/green white cut; weak yellow green residue stain. Sand (10010' -10040')=very light gray; clast medium lower to very fine upper; sub round to sub angular; moderate to poor sphericity; moderate sorting; impact texture; sub mature to mature nature; non to weak silic cement; unconsolidated with slight consolidated clusters; very slight clay matrix; grain supported; composed of>90% quartz; good porosity; fair to good permeability; 80% dull yellow green even sample fluorescence; spotty faint light brown oil stain; dull blue green translucent fluorescent cut; slow develop oil cut to poor/fair blue green white; weak yellow green residue stain. Sand (10080' -10160')=very light gray to light gray; clast medium upper to fine upper; sub round; moderate sphericity; moderate sorting; impact texture; sub mature nature; slight to moderate kaol matrix lithifying and pore filling agent unconsolidated with scattered sandstone clusters; grain support with secondary matrix support; composed of>90%quartz minor lithics; fair porosity and permeability; >80% dull yellow green even oil fluorescence; very faint spotty light brown oil stain; poor translucent dull yellow green oil cut; very faint yellow green residue stain Sand (10170' -10215')=same as above but slightly coarser with no matrix; >80% dull yellow green even fluorescence; no visible oil stain; instant light blue white translucent slow to moderate streaming oil cut; slow develop to moderate translucent blue white cut; slight dull yellow green residue stain. Sand/Siltstone(10215' -10225')= medium light gray to gray; lower coarse to upper fine; spherical to sub discoidal; very angular to sub angular; poorly sorted; unconsolidated; immature texturally; quartz; yellow gold fluorescence; no visible stain; slow streaming blue white cut no residual cut; dull yellow residual fluorescence. Coal/Carbonaceous Silt/Shale(10225'-10290') = black to grayish black; hard moderate to well indurated; splintery to conchoidal fracture. 19 CANRIG Chev on 14101 TRADING BAY UNIT M-11 3.2. FORMATION/ZONE MARKER TOPS Note: CT: Coal Top CB: Coal Base ST: Sand Top SB: Sand Base. ACTUAL FORMATION MD(ft) SSTVD(ft) Coal 531 -371 SZOCT 802 -642 SZOCB 807 -647 SZ1CT 862 -702 SZ1 CB 873 -713 SZ2CT 949 -789 SZ2CB 953 -793 SZ3CT 993 -832 SZ3CB 1001 -840 SZ4CT 1047 -886 SZ4CB 1073 -912 SZ5ST 1085 -924 SZ5CT 1130 -968 SZ5CB 1135 -973 SZ6ST 1148 -986 SZ6SB 1195 -1032 SZ6CT 1230 -1066 SZ6CB 1241 -1077 SZ7CT 1290 -1125 SZ7CB 1302 -1136 SZ8CT 1346 -1179 SZ8CB 1357 -1189 SZ9CT 1429 -1258 SZ9CB 1434 -1263 SZ10CT 1457 -1285 SZ10CB 1460 -1288 SZ11ST 1495 -1321 SZ11 BST 1533 -1357 SZ11BSB 1581 -1403 SZ11CT 1609 -1430 SZ11 CB 1626 -1446 SZ12ST 1642 -1461 SZ12SB 1689 -1506 SZ12CT 1693 -1509 SZ12CB 1712 -1527 SZ13ST 1731 -1545 SZ13CT 1772 -1584 SZ13CB 1778 -1590 SZ14ST 1784 -1595 SZ14CT 1838 -1646 SZ14CB 1845 -1653 SZ16ST 1865 -1671 SZ15CT 1909 -1712 SZ15CB 1913 -1716 SZ16SB 2071 -1860 SZ16CT 2075 -1863 20 CANRIG Chew on IWO TRADING BAY UNIT M-11 SZ16CB 2090 -1877 SZ17ST 2124 -1907 SZ17SB 2165 -1944 SZ17CT 2184 -1961 SZ17CB 2190 -1966 SZ18ST 2202 -1977 SZ18SB 2297 -2061 SZ18CT 2309 -2072 SZ18CB 2323 -2084 SZ19ST 2329 -2089 SZ19SB 2378 -2131 SZ19CT 2383 -2135 SZ19CB 2387 -2139 SZI 9STRT 2409 -2157 SZ19STRB 2415 -2162 SZ2OST 2421 -2168 SZ2OCT 2461 -2201 SZ2OCB 2468 -2207 SZ21CT 2561 -2286 SZ21CB 2579 -2301 SZ22ST 2605 -2323 SZ22SB 2621 -2336 SZ22CT 2629 -2343 SZ23ST 2643 -2355 SZ23SB 2658 -2368 SZ23AST 2687 -2392 SZ23ASB 2718 -2418 SZ23BST 2729 -2428 SZ23BCT 2763 -2456 SZ23BCB 2768 -2461 ACT 2788 -2477 ACB 2795 -2483 Al CT 2834 -2517 A2ST 2846 -2527 A2SB 2941 -2608 A2CT 2945 -2612 A2CB 2963 -2627 A2ASB 2982 -2644 A2ACT 2983 -2645 A3ST 3009 -2668 A3SB 3036 -2692 A4ST 3059 -2713 A4SB 3094 -2744 A4CT 3101 -2750 A5ST 3107 -2755 A5SB 3136 -2781 A5BST 3151 -2794 A5CST 3186 -2826 A5CT 3236 -2872 A5CB 3247 -2882 A6ST 3282 -2913 21 CANRIG Chevron 1111110 TRADING BAY UNIT M-11 A6SB 3309 -2938 A7ST 3333 -2960 BCT 3388 -3010 BCB 3415 -3035 B 1ST 3425 -3044 B1SB ____ 3450 -3067 B2ST 3478 -3093 B 1 CT 3523 -3135 B1 CB 3532 -3144 B3ST 3544 -3155 B4ST 3625 -3232 B4SB 3708 -3312 B2CT 3717 -3321 B2CB 3740 -3343 B5ST 3805 -3406 B4CT 3854 -3454 B4CB 3860 -3460 B6ST 3866 -3466 B6SB 3943 -3541 B5CT 3950 -3548 B5CB 3965 -3563 B7STRT 4005 -3602 B7STRB 4026 -3623 B8ST 4027 -3624 B8SB 4050 -3647 CCT 4094 -3690 CCB 4110 -3706 C1ST 4130 -3726 C 1 S B 4178 -3773 C 1 CT 4217 -3811 C2CT 4235 -3829 C2CB 4242 -3836 C3ST 4266 -3860 C3SB 4286 -3880 C4ST 4340 -3933 C3CT 4365 -3958 C3CB 4374 -3967 C7ST 4429 -4021 DCT 4454 -4046 DCB 4471 -4062 D1 ST 4493 -4084 D1 SB 4761 -4348 D1 CT 4763 -4350 D1 CB 4789 -4376 D2ST 4821 -4408 D2SB 4865 -4451 D2CT 4922 -4507 D2CB 4948 -4532 D2ACT 4972 -4556 D2ACB 4980 -4564 D3BST 4988 -4571 22 CANRIG Chevron WI TRADING BAY UNIT M-11 D3BSB 5033 -4616 D3CT 5117 -4698 D12ASB 6054 -4715 D12CT 6064 -4807 D12CB 6084 -4824 D13CT 6116 -4847 D13CB 6153 -4860 D14CT 6213 -4886 D14CB 6225 -4921 D15CT 6279 -4934 D15CB 6289 -4943 D16AST 6295 -5008 D16BST 6334 -5020 D16CST 6360 -5049 D16CSB 6389 -5112 D16DST 6410 -5157 D16CT 6424 -5161 D16CB 6435 -5199 D17ST 6450 -5252 D17CT 6526 -5271 D17CB 6534 -5300 D18ST 6540 -5306 ECT 6597 -5318 ECB 6608 -6072 9.625 Csg 6615 -6079 E1ST 6617 -6080 12-1/4 TD 6626 -6087 E1 SB 6788 -6216 E 1 CT 6862 -6275 E1 CB 6876 -6286 E2ST 6886 -6295 E2CT 6938 -6336 E2CB 6946 -6342 E3ST 6957 -6351 E3SB 6987 -6375 E3CT 7021 -6402 E3CB 7032 -6411 E4ST 7042 -6419 E4SB 7164 -6514 E4CT 7173 -6521 E4CB 7198 -6541 E5AST 7214 -6553 E5ASB 7349 -6655 E5ACT 7354 -6659 E5BST 7401 -6694 E5BSB 7486 -6756 E5CCT 7542 -6797 E6CT 7569 -6816 E7ST 7578 -6824 E7CT 7607 -6844 E7CB 7616 -6851 23 CANRIG 1111.0 TRADING BAY UNIT M-11 E9ST 7670 -6890 E9SB 7725 -6930 FCT 7735 -6936 FCB 7744 -6943 F1 ST 7769 -6961 F1 CT 7925 -7074 F2ST 7954 -7095 F2SB 7976 -7111 F2CT 8034 -7153 F3ST 8047 -7162 F3SB 8123 -7217 F3CT 8132 -7224 F4ST 8190 -7266 F4SB 8266 -7321 F4CT 8268 -7323 F5AST 8295 -7343 F5ASB 8347 -7380 F5BST 8348 -7381 F5BSB 8420 -7433 F6ST 8481 -7477 F6SB 8488 -7483 F6CT 8509 -7498 F6CB 8527 -7510 F7uST 8533 -7515 F7 Base Upper Sand 8555 -7531 F7 Top Mid Sand 8588 -7555 F7 Base Mid Sand 8591 -7557 F7CT 8631 -7586 F7CB 8652 -7601 F8AST 8665 -7611 F8ASB 8672 -7616 F8BST 8681 -7622 F8BSB 8700 -7636 F8CT 8732 -7660 F9ST 8791 -7703 F9CT 8823 -7726 F10CT 8901 -7782 F1OCB 8918 -7795 F11 ST 8933 -7806 F11 SB 8967 -7830 F11 CT 8981 -7841 F12CT 8999 -7854 F13BST 9042 -7884 F 13CT 9072 -7907 F14AST 9084 -7915 F 14AS B 9113 -7937 F14BST 9131 -7950 F14BSB 9144 -7958 F14CST 9154 -7966 F14CT 9171 -7978 24 CANRIG Chevron 1111.11 TRADING BAY UNIT M-11 F15AST 9196 -7996 F15ASB 9209 -8006 F15BST 9231 -8021 F15BSB 9319 -8085 F15CST 9337 -8098 F15CSB 9346 -8104 F15CT 9371 -8122 F16ST 9398 -8142 F16SB 9462 -8188 F17ST 9494 -8211 F17SB 9545 -8247 G01ST 9547 -8249 GST 9547 -8249 G01SB 9570 -8266 GO1CT 9590 -8280 GO1CB 9603 -8290 G02ST 9622 -8303 G02SB 9659 -8330 G03ST 9712 -8368 G03SB 9759 -8402 G04ST 9767 -8408 G04SB 9787 -8423 G05ST 9812 -8441 G05SB 9859 -8475 Coa139 9916 -8515 GIST 9933 -8528 G1SB 9978 -8560 G2ST 10003 -8578 G2SB 10037 -8603 G3ST 10116 -8659 G3SB 10143 -8679 G4ST 10166 -8696 G4SB 10228 -8741 TD 10290 -8785 25 CANRIG Chevron 1111110 TRADING BAY UNIT M-11 3.3. ZONE SUMMARIES Coal: 531' MD, -371' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 396.6 30.9 163.0 72 3 30 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 684' 72 13988 - - - - - - No samples collected until 1400' SZOCT: 802' MD, -642' SSTVD Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 200.2 108.1 171.7 13 12 12 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 802' 13 2710 - - - - - No samples collected until 1400'. SZ1 CT: 862' MD,-702' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 198.9 86.8 144.7 20 17 20 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 865' 20 3951 - - - - - - No samples collected until 1400' SZ2CT: 949' MD, -789' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 216.2 65.9 163.4 17 11 16 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 953' 17 3340 - - - - - - No samples collected until 1400'. 26 CANRIG Chevron 1111.0 TRADING BAY UNIT M-11 SZ3CT: 993' MD, -832' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 183.5 97.0 151.4 12 11 12 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 999' 12 2318 - - - - - - No samples collected until 1400'. SZ4CT: 1047' MD, -886' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 234.4 38.8 126.9 19 11 15 Peaks _Depth TG C1 C2 C3 C4I C4N C51 C5N 1052' 19 3830 - - - - - - No samples collected until 1400'. SZSST: 1085' MD, -924' SSTVD Drill Rate(ft/hr Total Gas(units _ Maximum Minimum Average Maximum Minimum Average 331.1 51.7 203.6 41 7 22 _Peaks Depth TG C1 C2 C3 C4I C4N _ C51 _ C5N 1127' 41 8256 - - - - - - No samples collected until 1400'. SZ5CT: 1130' MD, -968' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 142.3 67.0 129.5 34 22 27 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 1134' 34 6834 - - - - - - No samples collected until 1400'. 27 CANRIG Chevron 11400 TRADING BAY UNIT M-11 SZ6ST: 1148' MD, -986' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 389.1 74.0 221.0 29 10 23 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 1156' 29 5697 - - - - - - No samples collected until 1400'. SZ6CT: 1230' MD, -1066' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 100.6 43.0 65.0 34 14 26 Peaks Depth TG _ Cl C2 C3 C4I C4N C51 C5N 1241' 34 6724 - - - - - - No samples collected until 1400'. SZ7CT: 1290' MD, -1125' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 237.9 52.0 115.8 16 12 15 Peaks Depth TG _ C1 C2 C3 C4I C4N C51 C5N 1290' 154.2 3194 - - - - - - No samples collected until 1400'. SZ8CT: 1346' MD, -1179' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 79.7 41.4 72.2 32 14 23 _Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 1346' 32 6169 - - - - - - No samples collected until 1400'. 28 CANRIG Chevron IWO TRADING BAY UNIT M-11 SZ9CT: 1429' MD, -1258' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 75.1 53.4 81.5 145 48 127 Peaks Depth TG Cl C2 C3 C4I C4N _ C51 _ C5N 1429' 145 26787 - - - - - - Carbonaceous Shale/Coal = mottled brownish black to grayish black; brittle to firm; earthy to sub resinous lusters; matte texture; blocky to sub platy fracture along carbonaceous shale partings; composed of various grades of very carbon shale, sub lignite to lignitic coal; very slight visible gas from coal cuttings. SZ10CT: 1457' MD, -1285' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 66.3 11.5 35.0 80 12 41 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 1457 80 15967 - - - - - Coal =a small three foot coal section obscured by drill rates. SZ11ST: 1495' MD, -13521'SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 269.6 54.9 148.9 417 42 221 Peaks Depth TG Cl C2 . C3 C41 . C4N C5I C5N 1532' 417 83245 - - - - - - Sand =very light gray; clast size range medium lower to fine lower; sub angular to sub round; moderate developed sphericity; moderate sorting; impacted texture; sub mature nature; non to very slight silic cement; unconsolidated; dominant clay matrix; dominant matrix support with possible local grain support; loosely attached; composed of predominantly quartz with various lithic fragments; poor to fair porosity and poor permeability; no show of oil. 29 CANRIG Chevron 111.11 TRADING BAY UNIT M-11 SZ11 BST: 1533' MD, -1357' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 234.2 7.7 151.5 500 46 348 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 1577' 500 80536 - - - - - - Sand = medium gray to medium light gray; lower fine to upper very fine with occasional medium grains; sub-angular to sub-rounded; spherical to sub-discoidal; moderately to moderately well sorted; unconsolidated sand with some poorly consolidated sandstone; texturally immature; compositionally immature; translucent and milky white quartz with green lithics and black carbonaceous material; no fossils or structure noted; porosity and permeability visually fair; no oil indicators. SZ11CT: 1609' MD, -1430' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 245.0 92.5 199.1 372 166 305 Peaks Depth _ TG Cl C2 C3 C41 C4N C5I C5N 1621' 372 21950 - - - - - - Carbonaceous Shale/Coal = brownish black to black; earthy luster; tabular to sub-tabular cuttings habit; planar fracture; mottled texture; laminae to thin structure; no visible gas. SZ12ST: 1642' MD,-1461' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 363.0 100.2 227.5 350 4 220 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 1667' 350 20673 - - - - - - Sand (1680'-1710')= light gray to medium gray with brownish tones; lower to upper fine grains with upper medium to lower coarse grains of coal =20%; sand is sub rounded and poor to moderate sorting. 30 CANRIG Chevron 111110 TRADING BAY UNIT M-11 SZ12CT: 1693' MD, -1509' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 316.4 111.2 243.0 247 120 206 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 1712' 247 14601 - - - - - - Carbonaceous Shale/Coal = brownish black to black; earthy luster; tabular to sub-tabular cuttings habit; planar fracture; mottled texture; laminae to thin structure; no visible gas. SZ13ST: 1731' MD, -1545' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 324.7 68.9 190.9 327 44 204 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 1745' 327 19316 - - - - - - Tuffaceous Claystone = medium gray to medium light gray with light olive gray sub hues; poor induration; cohesive and adhesive; lumpy consistency; elastic to stiff tenacity; earthy fracture; massive cuttings habit; earthy to dull luster; clayey texture; scattered thin stringers of sand mostly interbedded within the silts. SZ13CT: 1772' MD, -1584' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 376.9 161.8 339.3 231 182 221 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 1778' 231 13635 - - - - - - No coal was observed in the samples. Scattered carbonaceous shale fragments noted. SZ14ST: 1784' MD, -1595' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 699.6 42.2 228.7 575 28 300 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 1830' 575 34932 - - - - - - 31 CANRIG Chew on IWO TRADING BAY UNIT M-11 Sand = light gray to gray; clast size ranges from medium upper to fine upper; sub angular to sub round; sub discoidal to moderate developed sphericity; moderate sorting; unconsolidated; friable sandstones scattered; moderate matrix support; texturally immature; compositionally immature; translucent quartz with greenstone and reddish brown to black carbonaceous material; no oil indicators. SZI4SCT: 1838' MD, -1646' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 282.7 99.6 201.3 525 323 520 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 1838' 525 31873 - - - - - - No coals were noted in the samples. Scattered carbonaceous shale fragments only. SZ16ST: 1865' MD, -1671' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 238.5 15.5 103.6 206 19 100 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 1878' 206 20586 - - - - - - Sand occurs as thinly laminated or thin beds in a matrix of tuffaceous claystone. SZ15CT: 1909' MD, -1712' SSTVD LDrill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 193.9 97.1 160.9 142 114 157 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 1911' 142 14224 - - - - - - No true coal is noted in the samples. Occurs as thin beds or micro laminations of very carbonaceous shale. SZ16CT: 2075' MD, -1863' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 146.0 58.3 111.5 190 20 108 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 32 CANRIG Chevron 1111110 TRADING BAY UNIT M-11 2087' 190 28590 - - - - - - Carbonaceous Shale/Coal= black to brownish black; hard in coal to firm in carbonaceous shale; planar fracture in carbon shale and irregular fracture in coal; resinous luster in coal to earthy luster in carbon shale; massive structure with laminations of carbonaceous shale. SZ17ST: 2124' MD, -1907' SS TVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 168.4 63.4 117.1 107 1 80 Peaks Depth TG Cl C2 C3 C4I C4N _ C51 C5N 2140' 107 16065 - - - - - - Sand = medium gray to medium light gray; clast size ranges from upper fine to lower fine grains; sub round to sub angular; moderate spherical to sub discoidal; moderate sorting; unconsolidated; moderate matrix silts and clays; texturally immature; compositionally immature;translucent quartz with black carbon fines and greenstone; trace feldspar; no oil indicators. SZ17CT: 2184' MD, -1961' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 201.1 136.4 203.7 381 94 286 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 2190' 381 70157 - - - - - - No coal was noticed in the samples. Scattered very carbon shale in small percentages. SZ18ST: 2202' MD, -1977' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 256.1 25.1 174.4 241 8 72 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 2282' 241 44491 - - - - - - Sand occurs as heavily interbedded within tuffaceous claystone. Less than 10%of the samples. 33 CANRIG Chevron IIMO TRADING BAY UNIT M-11 SZ18CT: 2309' MD, -2072' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 180.5 86.6 152.4 394 228 357 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 2313' 394 71870 - - - - - - Carbonaceous Shale/Coal = black to brownish black with reddish brown streaks; moderate to hard in coals to firm in carbon shale; planar fracture in carbon shale to irregular to sub conchoidal fractures in coals; sub tabular to irregular cuttings habit; laminated beds of immature reddish brown carbonaceous material with sub mature coal. SZ19ST: 2329' MD, -2089' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 317.0 49.9 225.5 366 2 242 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 2346' 366 66775 - - - - - - No sand was noted in the samples. Samples consisted of predominantly clays and silts. SZ19CT: 2383' MD, -2135' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 235.7 154.5 230.3 340 297 203 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 2385' 340 36290 - - - - - - No coal was noted in the samples. Thin stringers or laminations of very carbonaceous shale interbedded in massive tuffaceous clay. SZI9STRT: 2409' MD, -2157' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 187.6 15.7 138.5 239 109 232 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 2409' 239 19169 - - - - - - 34 CANRIG Chevron IMO TRADING BAY UNIT M-11 No sand was noted in this section. Occurs as very thin beds or interbedded within tuffaceous clay. SZ20ST: 2421' MD, -2168' SSTVD Drill Rate(ft/hr Total Gas (units _Maximum Minimum Average Maximum Minimum Average 238.7 89.1 181.3 179 2 74 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 2439' 179 14348 - - - - - - No sand was noted in this section. Occurs as very thin beds or interbedded within tuffaceous clay. SZ20CT: 2461' MD, -2201' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 197.7 119.5 168.8 120 8 62 Peaks Depth TG Cl C2 C3 C41 C4N v C51 C5N 2468' 120 9629 - - - - - - No coal is noted in the samples.Very thin carbon shale stringers or laminations in a massive matrix of tuffaceous clay. SZ21CT: 2561' MD, -2286' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 254.8 55.8 145.9 83 17 64 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 2562' 83 16620 - - - - - - Carbon Shale/Coal = black mottled grayish black to brownish black; firm becoming brittle in carbon shale; resinous and mottled earthy lusters; matte texture; blocky to sub planar fracture along carbonaceous shale partings; composed of very carbonaceous shale grading to lignitic coal; slight visible bleeding gas from most coal cuttings. SZ22ST: 2605' MD, -2323' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 185.0 52.7 106.2 28 16 26 Peaks 35 CANRIG Chevron 1100 TRADING BAY UNIT M-11 Depth TG Cl C2 C3 C4I C4N C5I C5N 2606' 28 5469 - - - - - - Sand =very light gray; clast size ranges from medium upper to fine lower; sub round to sub angular; moderate developed sphericity; moderate to poor sorting; impacted texture; immature to sub mature nature; no visible cement; unconsolidated; clay structured matrix with dominant matrix support with possible local grain support; matrix is loosely attached and very hydrophilic; composed of dominant quartz; fair to poor porosity and poor permeability; no show of oil. SZ22CT: 2629' MD, -2343' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 199.5 109.3 168.8 64 50 63 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 2632' 64 12590 - - - - - - Carbon Shale/Coal = black mottled grayish black to brownish black; firm becoming brittle in carbon shale; resinous and mottled earthy lusters; matte texture; blocky to sub planar fracture along carbonaceous shale partings; composed of very carbonaceous shale grading to lignitic coal; slight visible bleeding gas from most coal cuttings. SZ23ST: 2643' MD, -2355' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 199.3 40.8 146.3 50 94 163 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 2658' 50 9459 - - - - - - No sand was noted in the samples. Massive gradational tuffaceous silt and tuffaceous clay. SZ23AST: 2687' MD, -2392' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 264.6 30.5 205.1 48 20 3 Peaks Depth TG Cl C2C3 C41 C4N C5I C5N 2690' 48 9589 - - - - - - Sand occurs as 10% or less of the samples. Drill rate at the time was 200 ft/hr+. Possibility minor or thin sands are enveloped into the mud system. 36 CANRIG Chevron IWO TRADING BAY UNIT M-11 SZ23BST: 2729' MD, -2428' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 249.3 20.0 196.2 61 11 30 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 2762' 61 11999 - - - - - - Sand occurs as 10% or less of the samples. Drill rate at the time was 200 ft/hr+. Possibility minor or thin sands are enveloped into the mud system. SZ23BCT: 2763' MD, -2456' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 176.3 113.8 171.6 59 36 54 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 2763' 59 11503 - - - - - - Coal/Carbon Shale = black mottled grayish black to brownish black; firm to some hard coal fragments; earthy mottled resinous lusters; matte texture; blocky to sub planar fracture along carbonaceous shale partings; composed of very carbonaceous shale grading to lignitic coal; slightvisible bleeding gas from coal cuttings. ACT: 2788' MD, -2477' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 208.0 107.5 182.2 18 7 11 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 2788' 18 3580 - - - - - - Coal/Carbon Shale = black mottled grayish black to brownish black; firm to some hard coal fragments; earthy mottled resinous lusters; matte texture; blocky to sub planar fracture along carbonaceous shale partings; composed of very carbonaceous shale grading to lignitic coal; slight visible bleeding gas from coal cuttings with continued coal and carbonaceous shale samples as the SC23 coal section. A1CT: 2834' MD,-2517' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 208.7 63.5 164.4 105 4 76 37 CANRIG Chevron 1/110 TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 2840' 105 20123 - - - - - - No coal noted in the samples. Gas trap was being cleaned of massive drill cuttings build up. Low gas reading through this coal because of the low mud level as the gas trap was being cleaned. A2ST 2846' MD,-2527' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 184.1 25.8 102.4 165 71 137 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 2907' 165 31953 - - - - - - Sand =very light gray; clast size ranges from coarse lower to fine upper; sub angular to sub round; moderate developed sphericity; moderate sorting; mean grain size is medium; impacted texture; sub mature nature; no visible silic cement; unconsolidated; clay and silt matrix; matrix supported with local grain support in parts; hydrophilic clay matrix which is loosely attached; composed of quartz with secondary chert and minor various lithic fragments; fair to poor porosity and poor permeability; no show of oil fluorescence or oil cut. A2CT: 2945' MD,-2612' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 226.6 112.1 188.0 465 207 400 Peaks Depth TG Cl C2 C3 C4I C4N C51 _ C5N 2951' 465 91614 - - - - - - Carbonaceous Shale/Coal = black mottled brownish black to grayish black; firm to hard; earthy mottled resinous lusters; irregular to sub blocky fracture; composed of lignitic coal grading to carbonaceous shale; visible bleeding gas from most coal cuttings. A2ACT: 2983' MD, -2645' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 251.1 99.1 187.2 143 58 98 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 3009' 143 26321 - - - - - - Carbonaceous Shale/Coal = black mottled brownish black to grayish black; firm to hard; earthy mottled resinous lusters; irregular to sub blocky fracture; composed of lignitic coal grading to 38 CANRIG Chevron 111110 TRADING BAY UNIT M-11 carbonaceous shale; visible bleeding gas from most coal cuttings with continued carbon shale and coal continuity from the A2. A3ST: 3009' MD, -2668' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 246.5 19.7 174.8 161 82 127 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 3011' 161 31178 - - - - - - Scattered fine to medium sand and sandstone with abundant matrix support interbedded with massive tuffaceous claystone. Sands make up only 10-30%of the samples. A4ST: 3059' MD, -2713' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 215.8 100.0 174.0 120 23 9 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 3063' 120 23561 - - - - - - Continued minor medium to fine grained sand interbedded or thinly bedded with massive tuffaceous clays and tuffaceous silt. A4CT: 3101' MD, -2750' SSTVD _ Drill Rate(ft/hr _ Total Gas(units Maximum Minimum Average Maximum Minimum Average 234.7 138.5 203.6 162 131 172 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 3101' 162 31265 - - - - - - Occurs as thinly bedded very carbonaceous shale with no true coals noted with carbonaceous shale's making up 10-20% of the samples. Drill rate was 175-200 ft/hr. A5ST: 3107' MD, -2755' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 261.7 27.4 183.5 131 68 104 Peaks 39 CAIVRIG C TRADING BAY UNIT M-11 Depth TG Cl _ C2 C3 C4I C4N C5I C5N 3107' 131 25290 - - - - - - Sand =very light gray; clast size ranges from medium upper to fine lower; sub round; moderate to well developed sphericity; equant grain sphericity; fair to poor sorting; polish to impacted textures; immature to sub mature nature; non to very slight silic cement; clay structured matrix with secondary grain support; the matrix is hydrophilic and loosely attached; composed of predominantly quartz with minor chert and trace lithic fragments; fair to poor porosity with poor permeability; no show of oil fluorescence or oil cut. A5BST: 3151' MD, -2794' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 289.9 48.0 218.6 145 93 127 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 3177' 145 28560 - - - - - - Sand =very light gray; clast size ranges from coarse lower to medium lower; sub round; moderate to well developed sphericity; equant grain sphericity; scattered beds of minor tuffaceous sandstone and conglomerate sand; fair to poor sorting; polish to impacted textures; immature to sub mature nature; non to very slight silic cement; clay structured matrix with secondary grain support; the matrix is hydrophilic and loosely attached; composed of predominantly quartz with minor chert and trace lithic fragments; fair to poor porosity with poor permeability; no show of oil fluorescence or oil cut. A5CST: 3186' MD, -2826' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 341.9 14.4 184.0 347 60 150 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 3233' 347 67258 - - - - - - Sand =very light gray; clast size ranges from coarse lower to medium lower; sub round; moderate to well developed sphericity; equant grain sphericity; scattered beds of minor tuffaceous sandstone and conglomerate sand; fair to poor sorting; polish to impacted textures; immature to sub mature nature; non to very slight silic cement; clay structured matrix with secondary grain support; the matrix is hydrophilic and loosely attached; composed of predominantly quartz with minor chert and trace lithic fragments; fair to poor porosity with poor permeability; no show of oil fluorescence or oil cut. A5CT: 3236' MD, -2872' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 198.5 141.7 184.1 324 73 185 Peaks 40 CANRIG Chevron TRADING BAY UNIT M-11 Depth TG Cl C2 C3 C4I C4N C51 C5N 3236' 324 61771 - - - - - - Coal/Carbonaceous Shale= black mottled brownish black to grayish black; firm to hard; earthy mottled resinous luster; matte texture; blocky to irregular fractures; composed of sub lignitic to lignitic coal with thin laminae to micro laminae of very carbon clay and/or shale; visible bleeding out gas from coal cuttings. A6ST: 3282' MD, -2913' SSTVD LDrill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 236.2 79.7 151.9 82 33 56 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 3290' 82 15730 - - - - - - Sand and Conglomerate Sand =very light gray to pinkish gray; clast size ranges from coarse upper to medium lower; sub angular to sub round; moderate developed sphericity; poor sorting; chipped to impacted textures; sub mature nature; non to very slight silic cement; loose grains with silt and clay structured matrix; loose matrix support with grain support locally; hydrophilic matrix; composed of quartz with secondary chert with trace metamorphic, greenstone and tuff fragments; poor porosity and permeability; no show of oil fluorescence or oil cuts. A7ST: 3333' MD, -2960' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 357.2 46.6 232.4 282 68 92 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 3382' 282 50896 - - - - - - Sand and Conglomerate Sand =very light gray to pinkish gray; clast size ranges from coarse upper to medium lower; sub angular to sub round; moderate developed sphericity; poor sorting; chipped to impacted textures; sub mature nature; non to very slight silic cement; loose grains with silt and clay structured matrix; loose matrix support with grain support locally; hydrophilic matrix; composed of quartz with secondary chert with trace metamorphic, greenstone and tuff fragments; poor porosity and permeability; no show of oil fluorescence or oil cuts BCT; 3388' MD, -3010' SSTVD Drill Rate(ft/hr) . Total Gas (units Maximum Minimum Average Maximum Minimum Average 243.3 41.8 153.5 289 6 66 Peaks 41 CANRIG Chevron 1140 TRADING BAY UNIT M-11 Depth TG Cl C2 C3 C4I C4N C51 C5N 3389' 289 51782 54 49 - - - - Coal/Carbonaceous Shale and Carbonaceous Clay= black mottled brownish black and grayish black;firm to hard; some dense cuttings; earthy mottled resinous lusters; general matte texture; sub blocky to irregular fractures; composed of predominantly lignitic to sub lignitic coal with micro laminations of very carbonaceous clay and carbonaceous shale; visible bleeding gas from most coal cuttings. B1ST; 3425' MD, -3044' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 543.3 20.7 116.1 26 11 18 Peaks Depth TG _ Cl C2 C3 C41 _ C4N C51 C5N 3435' 26 5090 - - - - - - Only minor sand was noted in the samples. Sand percentage was only 10%through this section with stable drill rates and gas readings. B2ST; 3478' MD, -3093' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 180.9 21.7 82.0 26 3 1 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 3523' 26 4979 - - - - - - Only minor sand was noted in the samples. Sand percentage was only 10%through this section with stable drill rates and gas readings B1CT; 3523' MD, -3135' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 193.2 46.3 187.1 70 26 66 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 3530' 70 13374 - - - - - - Samples noted only 40% carbonaceous shale and clay but a drill break from 80 ft/hr to 190 ft/hr and resulting gas kick from 10 units to 70 units indicates a larger coal or carbonaceous shale. 42 CANRIG Chevron TRADING BAY UNIT M-11 B3ST; 3544' MD, -3155' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average - Maximum Minimum Average 132.4 20.9 69.8 21 3 9 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 3544' 21 4134 - - - - - - Sand/Sandstone=very light gray; clast size ranges from medium upper to fine lower; moderate sphericity; moderate sorting; impacted texture; non to weak silic cement; sand with sandstone clusters; sub mature nature; clay matrix support and grain support; fair to poor porosity and permeability; no oil indicators. B4ST; 3625' MD, -3232' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 182 13 88 11 4 8 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 3668 11 2217 - - - - - - Sand/Conglomerate Sand =very light gray; clast size ranges from coarse lower to fine upper; sub round; moderate developed sphericity; fair to poor sorting; impacted to pitted textures; sub mature nature; non to very weak silic cement; unconsolidated or interbedded with matrix support; scattered local grain support; moderate to abundant hydrophilic clay matrix loosely attached; composed predominantly of quartz with secondary chert with minor lithics; fair to poor porosity and permeability; gradational beds of conglomerate sand and sand: grading to increased matrix support by 3690'; no show of oil fluorescence or oil cut. B2CT; 3717' MD, -3321' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 187 25 55 43 7 25 Peaks Depth TG C1 _ C2 C3 C41 C4N C51 C5N 3731 43 8677 - - - - - - Coal/Carbonaceous Clay= black mottled/striated brownish black; firm to hard; earthy/striated resinous to earthy luster; matte to striated texture; irregular to blocky fracture; composed of lignitic coal striated with brown micro laminae of very carbonaceous clay; visible bleeding gas from coal cuttings. 43 CANRIG Chevron 11111111 TRADING BAY UNIT M-11 B5ST; 3805' MD, -3406' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 133 15 58 51 9 19 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 3854 51 9776 - - - - - - Sand/Sandstone= light gray to medium light gray with a salt and pepper appearance; predominantly lower coarse to medium lower; sub angular to sub rounded; moderate sphericity with discoidal grains; moderate sorting; unconsolidated to well consolidated in parts; milky white quartz with chert with various black lithics and greenstone;fair porosity and permeability; no show of oil fluorescence or cut. B4CT; 3854', -3454' SSTVD L__ Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 120 50 113. 51 40 55 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 3855' 51 9776 - - - - - - Carbonaceous Shale/Coal =grayish black to black; brittle to crumbly tenacity; planar to conchoidal fractures; sub tabular cuttings habit; greasy luster; matte texture; laminae structure; no bleeding gas observed. B6ST; 3866' MD, -3466' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 639 17 151 64 9 31 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 3897' 64 12885 - - - - - - Sand/Sandstone= light gray to medium light gray with a salt and pepper appearance; predominantly lower coarse to medium lower; sub angular to sub rounded; moderate sphericity with discoidal grains; moderate sorting; unconsolidated to well consolidated in parts; milky white quartz with chert with various black lithics and greenstone; fair porosity and permeability; no show of oil fluorescence or cut. B5CT; 3950' MD, -3548' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 170.2 95.2 122.9 144 25 102 44 CANRIG row TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 _ C3 C4I C4N C5I C5N 3958' 144 24903 - - - - - - Carbonaceous Shale/Coal = brownish black to black; overall brittle; planar to conchoidal to splintery fractures; tabular and splintery cuttings habit; greasy to waxy luster; matte texture; laminae structure with visible bleeding gas from cuttings. B7STRT; 4005' MD, -3602' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 154 131 150 65 55 65 Peaks Depth TG _ Cl C2 C3 C41 C4N C51 C5N 4013' , 65 13102 - - - - - - Sand observed was less than 10%. Possible sand stringers only in a tuffaceous silt and tuffaceous clay. B8ST: 4027' MD, -3624' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 139 16 88 55 23 38 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 4027' 55 11065 26 - - - - - Continued small stringers of medium to fine grain sand. CCT; 4094' MD, -3690' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 146 54 124 200 116 177 Peaks Depth TG Cl C2 _ C3 C41 C4N _ C5I C5N 4098' 200 27179 269 - - - - - Coal/Carbonaceous Shale= black to brownish black; firm to hard; some becoming brittle in carbon shale; planar to conchoidal fracture; tabular to sub tabular cuttings habit; waxy to dull luster; laminae structure; some out gassing noted. 45 CANRIG Chevron 11111101 TRADING BAY UNIT M-11 C1ST;4130' MD, -3726' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 100 12 44 64 11 37 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 4135' 64 8901 107 - - - - - Sand/Sandstone= medium light gray to light gray with salt and pepper appearance; medium lower to fine upper; moderate sphericity with some sub discoidal grains; angular to sub angular; moderate sorting; unconsolidated; translucent and smokey quartz with carbon fines; fair to good porosity and permeability; no show of oil fluorescence or oil cut. C1CT;4217' MD, -3811' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 118 93 116 262 13 155 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 4219' 262 40882 430 - - - - Coal/Carbonaceous Shale= black to brownish black; firm to hard; planar to conchoidal fracture; tabular cuttings habit; dull to waxy luster; matte texture; visible out gassing. C2CT; 4235' MD, -3829' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 122 104 128 209 156 216 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 4237' 209 32772 276 - - - - - Coal/Carbonaceous Shale = black to brownish black; firm to hard; planar to conchoidal fracture; tabular cuttings habit; dull to waxy luster; matte texture; visible out gassing. C3ST;4266' MD, -3860' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average _ Maximum Minimum Average 95 19 63 44 30 42 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 4283' 44 8898 32 - - - - - 46 CANRIG CAevron IWO TRADING BAY UNIT M-11 Sand is less than 10% of the samples and occurs as thin stringers. C4ST;4340' MD, -3933' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum . Average Maximum Minimum Average 129 12 93 226 33 117 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 4363' 226 43918 179 56 - - - - Sand is less than 10% of the samples and occurs as thin stringers interbedded within massive tuffaceous silts. C3CT; 4365' MD, -3958' SSTVD Drill Rate(ft/hr _ Total Gas(units Maximum Minimum Average Maximum Minimum Average 132 85 125 205 85 155 Peaks Depth TG Cl C2 C3 C4l C4N C51 C5N 4365' 205 39923 161 55 Carbonaceous Shale/Coal = grayish black striated black; firm; earthy micro laminations of resinous luster and earthy luster; matte to striated textures; sub planar fractures along shale partings; composed of very carbonaceous shale and lignitic coal; trace visible bleeding gas from coal cuttings. C7ST; 4429' MD, -4021' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 115 71 97 392 126 198 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 4453' 392 30675 290 - - - - - No visible sand in this section which is composed by tuffaceous silts, tuffaceous clays and minor ash. DCT; 4454' MD, -4046' SSTVD Drill Rate(ft/hr Total Gas (units _ Maximum Minimum Average Maximum Minimum Average 172 71 127 378 134 231 Peaks _ Depth TG Cl C2 C3 C4I C4N C5I C5N 4454' 378 28824 276 - - - - - 47 CANRIG Chevron IWO TRADING BAY UNIT M-11 Carbonaceous Shale/Coal = grayish black striated black; firm; earthy micro laminations of resinous luster and earthy luster; matte to striated textures; sub planar fractures along shale partings; composed of very carbonaceous shale and lignitic coal; trace visible bleeding gas from coal cuttings. DIST; 4493' MD, -4084' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 214 6 82 174 2 52 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 4515' 174 31006 211 18 - - - - Conglomerate Sand =very light gray; clast size ranges from pebble to medium lower; sub round to some angular bit impacted fragments; moderate developed sphericity with poor sphericity in coarse grains; fair to poor sorting; polished texture; sub mature nature; no visible cement; unconsolidated; grain supported; slight hydrophilic clay matrix; composed of predominantly quartz with secondary chert and various lithic fragments; good porosity; no oil fluorescence or oil cuts. DICT; 4763' MD, -4350' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 179 37 109 277 51 207 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 4779' 277 25806 294 26 - - - - Coal/Carbonaceous Shale = grayish black mottled black; brittle to firm; earthy mottled resinous luster; striated to matte texture; irregular to sub planar fracture along very carbonaceous shal partings; composed of lignite and very carbonaceous shale; slight bleeding gas from coal cuttings. D2ST; 4821' MD, -4408' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 177 18 115 35 9 21 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 4846 35 11231 62 - - - - - Conglomerate/Conglomerate Sand =very light gray; clast size ranges from coarse upper to fine lower; sub round to sub angular to angular bit impacted fragments with moderate to poorly developed sphericity; poorly sorted; chipped and polished textures; sub mature nature; no visible cement; unconsolidated; grain support with local silt/clay support; slight to moderate hydrophilic clays; no oil fluorescence or oil cuts. D2CT; 4922' MD, -4507' SSTVD 48 CANRIG Chevron IRO TRADING BAY UNIT M-11 Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 166 45 126 260 179 238 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 4924' 260 23809 286 82 - - - - Coal/Carbonaceous Clay= grayish black mottled grayish brown with micro laminations of carbon clay; firm; earthy striated resinous luster; matte to striated textures; composed of lignite and very carbonaceous clay; visible bleeding gas from most cuttings. D2ACT;4972' MD, -4556' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 121 41 84 145 3 61 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 4972' 145 18273 100 16 - - - - Coal/Carbonaceous Clay= grayish black mottled grayish brown with micro laminations of carbon clay; firm; earthy striated resinous luster; matte to striated textures; composed of lignite and very carbonaceous clay; visible bleeding gas from most cuttings. D3BST;4988' MD, -4571' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 91 29 77 92 2 43 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 4997' 92 15963 67 - - - - - Sand =very light gray; clast size ranges from medium upper to fine lower; sub round; moderate to well developed sphericity; moderate to poor sorting; polished texture; sub mature nature; no visible cement; moderate to abundant hydrophilic clay matrix which is loosely attached; dominant matrix support; poor porosity and permeability; composed of quartz with secondary chert and thin laminations of coal fines and various detrital material; matrix material increases with depth; no show of oil fluorescence or oil cut. D3CT; 5177' MD, -4698' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 94 40 85 201 86 165 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 49 CANRIG Chevron WI TRADING BAY UNIT M-11 5177' 201 36664 208 - - - - - No visible coal in the samples which contain abundant tuffaceous siltstone. If any coal is in place it would be very small beds or stringers. D4CT; 5228' MD, -4807' SSTVD Drill Rate(ft/hr Total Gas (units • Maximum Minimum Average Maximum Minimum Average 116 34 91 406 55 219 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5238' 406q 28796 251 39 - - - - Coal/Carbonaceous Shale= black mottled grayish brown; firm some hard; resinous laminated earthy lusters; matte to striated textures; irregular fracture; composed of lignitic coal with micro laminations of very carbonaceous material. D5CT; 5269' MD, -4847' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average _ Maximum Minimum Average 81 49 75 368 35 127 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 5269' 368 55324 410 - - - - - Coal/Carbonaceous Shale = black mottled grayish brown; firm some hard; resinous laminated earthy lusters; matte to striated textures; irregular fracture; composed of lignitic coal with micro laminations of very carbonaceous material. D6ST: 5309' MD, -4886' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 164 26 97 75 41 55 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 5345' 75 8835 41 - - - - - Sand =gray to medium gray; bimodal sand with very coarse upper to course upper and medium upper to medium lower matrix sands; angular to sub angular; low developed sphericity with discoidal grains; very poor to poorly sorted; unconsolidated; texturally immature to compositionally immature; milky white and translucent quartz; with minor feldspar; good porosity and permeability; no oil florescence or oil cuts. 50 CANRIG Chevron 111010 TRADING BAY UNIT M-11 D6CT: 5358' MD, -4934' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average _ Maximum Minimum Average 99 69 96 441 56 277 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 5367' 441 72892 431 - - - - - Carbonaceous Shale = black to grayish black; firm to hard; brittle to dense ranging from carbon clay to lignitic coal; planar to splintery to conchoidal fractures; tabular to sub tabular cuttings habit; earthy luster; matte texture; laminae structure. D7CT: 5434' MD, -5008' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 146 103 146 380 76 279 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 5440' 380 62778 348 - - - - - Coal = black to dark gray with dark brown hues; reddish brown carbon clay or iron oxide; brittle to hard ranging from carbon clay to coal; dull to earthy luster; irregular to conchoidal fracture; bleeding gas prevalent in coal fragments. D8ST: 5475' MD, -5049' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 192 6 129 105 2 66 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 5520' 105 17408 89 - - - - - Sand = light gray; clast size ranges from medium lower to fine lower; sub round; moderate developed sphericity; poor to moderate sorting; unconsolidated; grain supported; composed of 90% quartz, 10% various lithic fragments; fair porosity and permeability; no show of oil fluorescence or oil cut. D8CT: 5586' MD, -5157' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 107 84 88 235 58 203 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 5590' 235 38884 186 - - - - - 51 CANRIG Chevron ISO TRADING BAY UNIT M-11 Coal = black mottled dark gray; brittle in carbon shale to hard in coal; irregular fracture; earthy to resinous luster; visible out gassing in coal fragments. D9ST; 5630' MD, -5199' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 182 10 144 67 12 40 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 5630' 67 6451 28 - - - - - Sand = light gray; clast size ranges from coarse lower to medium lower; moderate sorting; sub angular to sub rounded; unconsolidated with weakly consolidated clusters; grain supported with slight clay matrix; composed of 90%quartz, 10% chert and various lithic fragments; fair porosity and permeability; no show of oil fluorescence or oil cut. D9AST: 5705' MD, -5271'SSTVD Drill Rate(ft/hr) _ Total Gas (units Maximum . Minimum Average Maximum Minimum Average 129 68 96 59 20 39 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 5735' 59 5736 19 - - - - - Sand = light to medium gray; clast size ranges from coarse lower to medium; angular to sub angular; poor to moderate sorting; unconsolidated with scattered weakly cemented clusters; grain supported; sub mature to mature nature; composed of 80% quartz, 20% chert, feldspar and various lithic fragments; fair porosity and permeability; no show of oil fluorescence or oil cuts. D9CT: 5735' MD, -5300' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 129 80 95 237 59 171 Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 5741' 237 22776 71 - - - - - Coal = black to dark gray with moderate to dark brown hues; brittle to hard; earthy to shiny lusters; mottled with irregular fractures; visible bleeding gas from most coal cuttings; composed of bituminous to lignitic coal. 52 CANRIG Chevron 111110 TRADING BAY UNIT M-11 D10ST: 5754' MD, -5318' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 160 24 120 70 10 41 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 5754' 70 6788 20 - - - - - Sand = light to medium gray; clast size ranges from coarse lower to medium grains; angular to sub angular rounding; poor to moderate sorting; unconsolidated with slight consolidated clusters weakly cemented; grain supported with slight matrix support locally; composed of 80%quartz with 20% chert, feldspars, coal fines and various lithic fragments; fair porosity and permeability; no show of oil fluorescence or oil cuts. D10AST: 5815' MD, -5376' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 146 21 104 49 16 39 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 5827' 49 4719 10 - - - - - Sand = light to medium gray; clast size ranges from fine upper to fine lower; sub rounded to sub angular; well sorted grains of consistent size; unconsolidated; grain supported; mature nature; good porosity and permeability; composed of 80%quartz, 20%chert,feldspar and various lithic fragments; no oil fluorescence or oil cuts. D10CT: 5885' MD, -5442' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 103 60 96 390 43 294 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 5891' 390 37539 56 - - - - - Coal= black to dark gray with dark brown to reddish brown hues; brittle to hard; dull to earthy lusters; laminated with carbonaceous shale and clay. D11ST: 5916' MD, -5471' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 118 29 85 47 21 37 Peaks 53 CANRIG Chevron 11110 TRADING BAY UNIT M-11 Depth TG Cl C2 C3 C41 C4N C51 C5N 5926' 47 4570 5 - - - - - Sandy Siltstone=dark brown to dark gray; dense in parts; silty texture; dull earthy luster; trace interbedded coarse quartz grains; grading to very fine grain sandstone and scattered thin sand beds. D11CT: 5933' MD, -5487' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 135 73 125 402 32 219 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 5942' 402 38731 36 - - - - -- Coal = black to dark gray; brittle to hard; matte texture; earthy to resinous luster; irregular to conchoidal fracture; composed of bituminous coal and minor carbon shale. D12ST: 5950' MD, -5503' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 173 26 112 99 9 38 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 5957' 99 9583 7 - - - - - Sand = light gray; clast size ranges from medium lower to fine upper; sub angular to sub round; moderate to well sorted; unconsolidated and matrix supported; composed of 80% quart, 20% chert, feldspar, mica and various lithic fragments; some scattered sandstone clusters; fair porosity and permeability; no show of oil fluorescence or oil cuts. D12AST; 5991' MD, -5541' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average , Maximum Minimum Average 190 8 117 65 9 42 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6024' 65 6314 1 - - - - - Conglomerate Sand/Conglomerate=very light gray; clast size ranges from very coarse to medium lower; sub angular to sub round; scattered angular bit impacted fragments; poor to moderate developed sphericity; poorly sorted; polished coarse grains to impacted medium grains; sub mature nature; non to weak silic cement; unconsolidated with scattered clusters of medium to coarse grained sandstone; non to slight visible hydrophilic clay matrix; dominant grain support; composed of predominantly quartz with 54 CANRIG Chevron 1111101 TRADING BAY UNIT M-11 secondary chert and minor dark lithics; fair to good porosity and permeability; no show of oil fluorescence or oil cut. D12CT: 6064' MD, -5607' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 63 32 48 279 66 210 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6070' 279 39876 406 69 - - - - Coal/Carbonaceous Shale and Carbonaceous Clay= brownish black mottled black; brittle to firm; predominantly earthy luster with micro laminations to a mottled resinous luster; matte to striated textures; predominantly sub planar fracture along shale laminations; composed of sub lignitic to very carbonaceous shale and very carbonaceous clay;trace amber and plant fossils; visible bleeding gas from fresh cuttings; occurs as thin to thick beds with silts and clays D13CT; 6116' MD, -5654' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 75 23 59 223 33 80 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 6134' 223 38697 370 60 - - - - Coal/Carbonaceous Shale and Carbonaceous Clay= brownish black mottled black; brittle to firm; predominantly earthy luster with micro laminations to a mottled resinous luster; matte to striated textures; predominantly sub planar fracture along shale laminations; composed of sub lignitic to very carbonaceous shale and very carbonaceous clay;trace amber and plant fossils; visible bleeding gas from fresh cuttings; occurs as thin to thick beds with silts and clays; continuous very carbonaceous shale and coal from the D12. D14CT; 6213' MD, -5740' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 91 26 85 255 50 199 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6216' 255 25503 254 34 - - - - Coal/Carbonaceous Shale= black; brittle to firm; predominantly earthy luster with micro laminations to mottled resinous lusters; matte to striated textures; predominantly sub planar fracture along shale laminations; composed of sub lignite to very carbonaceous shale and carbon clay; trace amber and plant 55 CANRIG Chevron 11111101 TRADING BAY UNIT M-11 fossils; visible gas bleeds from fresh coal cuttings; occurs as thin to thick beds with carbon silt and carbon clay. D15CT: 6279' MD, -5798' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 92 52 87 244 89 219 Peaks Depth TG Cl _ C2 C3 C4I C4N C5I C5N 6284' 244 52553 450 61 - - - - Coal/Carbonaceous Shale= black; brittle to firm; predominantly earthy luster with micro laminations to mottled resinous lusters; matte to striated textures; predominantly sub planar fracture along shale laminations; composed of sub lignite to very carbonaceous shale and carbon clay; trace amber and plant fossils; visible gas bleeds from fresh coal cuttings; occurs as thin to thick beds with carbon silt and carbon clay with continued very carbonaceous shale and coal as the D14 coal. D16AST: 6295' MD, -5812' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 80 30 67 95 19 42 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 6326' 95 13689 87 42 - - - - No sand was noted in the samples which consisted of tuffaceous siltstone. D16BST: 6334' MD, -5845' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 83.8 13.0 61.7 88 10 39 Peaks Depth TG Cl C2 C3 _ C4I C4N C5I C5N 6346' 88 16712 101 24 - - - - No sand was noted in the samples which consisted of tuffaceous siltstone. D16CST: 6360' MD, -5868' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 86 36 68 31 10 22 56 CANRIG Chevron 140 TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6363' 31 5814 46 - - - - - Sand/Conglomerate Sand =very light gray; clast size ranges from coarse upper to fine upper; no abundant size faction; moderate developed sphericity; poorly sorted; impacted medium grains to polished coarse grains; sub mature nature; non to very weak silic cement; unconsolidated sands with scattered loosely consolidated clusters with a clay matrix; overall grain supported with secondary local matrix support; composed of quartz with secondary chert and minor lithics; fair porosity and permeability; no show of oil fluorescence or oil cuts. D16DST: 6410' MD, -5910' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 74 51 63 38 23 32 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 6416' 38 6290 35 - - - - - Sand/Conglomerate Sand =very light gray; clast size ranges from coarse upper to fine upper; no abundant size faction; moderate developed sphericity; poorly sorted; impacted medium grains to polished coarse grains; sub mature nature; non to very weak silic cement; unconsolidated sands with scattered loosely consolidated clusters with a clay matrix; overall grain supported with secondary local matrix support; composed of quartz with secondary chert and minor lithics; fair porosity and permeability; no show of oil fluorescence or oil cuts. Continued conglomerate sand from the D16C. D16CT: 6424' MD, -5922' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 74 55 74 271 28 168 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 6431' 271 35513 370 46 - - - - Coal/Carbonaceous Shale= black; brittle to firm; predominantly earthy luster with micro laminations to mottled resinous lusters; matte to striated textures; predominantly sub planar fracture along shale laminations; composed of sub lignite to very carbonaceous shale and carbon clay; trace amber and plant fossils; visible gas bleeds from fresh coal cuttings; occurs as thin to thick beds with carbon silt and carbon clay. D17ST: 6450' MD, -5944'SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 113 10 71 62 1 16 57 CANRIG Chevron ISO TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6526' 62 11510 67 19 - - - - Conglomerate Sand/Sand =very light gray; clast size ranges from very coarse lower to fine upper; angular coarse bit impacted grains to sub round medium grains; poor to moderate sphericity; abundant faction of coarse and medium matrix sands; very poor sorting; chipped coarse grains to impacted medium grains; sub mature nature; non to weak silic cement; unconsolidated to scattered loosely consolidated clusters with a hydrophilic clay matrix; composed of 90% quartz, 10% chert and various lithic grains; fair to good porosity and permeability; no show of oil fluorescence or oil cuts. D17CT: 6526' MD, -6006' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 70 23 52 81 29 71 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 6530' 81 14816 91 26 - - - - Carbonaceous Shale/Coal =black to grayish black; moderately hard in coal fragments to brittle in carbon shale; planar and conchoidal fractures; resinous luster overall; laminae structure with no visible bleeding gas from the coal cuttings. D18ST: 6540' MD, -6018' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 65.7 22.3 47.1 31 2 11.0 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6597' 31 6123 37 3 - - - - No sand was present in this section with mostly tuffaceous siltstone with scattered sands at 10%and less and interbedded. ECT: 6597' MD, -6064' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 66 34 59 118 31 84 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 6601' 118 23163 154 Carbonaceous Shale/Coal= black to grayish black; firm to hard in coals to brittle in carbonaceous shale; planar fracture in carbon shale to conchoidal fracture in coal; overall resinous luster with a laminae structure. 58 CANRIG Chevron 140 TRADING BAY UNIT M-11 E1 ST: 6617' MD, -6075' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum _ Average Maximum _ Minimum Average 165 11 95 13 0 4 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 6627' 13 25595 Sand =very light gray; clast size range medium upper to fine upper; sub round; moderate to well developed sphericity; moderate sorting; polished texture; sub mature nature; no visible cement; unconsolidated; clay matrix loosely attached; matrix support with secondary local grain support; poor porosity and permeability; compose of>90%quartz; no oil. E1CT: 6862' MD, -6275' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum _ Minimum Average 96.6 56.1 89.1 124 26 105.7 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 6867' 124 22432 157 36 Carbonaceous Shale/Coal =grayish black mottled brownish black; firm; brittle in carbon shale to firm in coals; earthy mottled resinous luster; matte to striated texture; irregular to planar fracture along shale partings; visible bleeding gas from coal cuttings. E2ST: 6886' MD, -6295' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 94.0 20.9 75.5 46 4 10.1 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 6938' 46 5240 120 Tuffaceous Siltstone=grayish orange; very poor to poor induration; slightly sectile; lumpy to clumpy; clustered to clotted; mushy to pasty; hydrophilic; slightly cohesive; moderate adhesive; amorphous to sub earthy fracture; sub nodular habit; earthy luster; silty to clayey textures; gradational beds of silt and clay; small carbonaceous shale/coal at 6940'. E2CT: 6938' MD, -66336'SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 79.1 54.8 85.1 79 17 63.8 59 CANRIG Chevron TRADING BAY UNIT M-11 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 6942' 79 8871 198 Tuffaceous Siltstone= grayish orange; very poor to poor induration; slightly sectile; lumpy to clumpy; clustered to clotted; mushy to pasty; hydrophilic; slightly cohesive; moderate adhesive; amorphous to sub earthy fracture; sub nodular habit; earthy luster; silty to clayey textures; gradational beds of silt and clay; small carbonaceous shale/coal at 6940'. E3ST: 6957' MD, -6351' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 85.2 56.0 83.7 15 6 12.0 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 6968' 15 2602 42 Sand =very light gray; clast size range medium upper to fine upper; sub round; moderate to well developed sphericity; moderate sorting; polished texture; sub mature nature; no visible cement; unconsolidated; clay matrix loosely attached; matrix support with secondary local grain support; poor porosity and permeability; compose of>90%quartz; no oil. E3CT: 7021' MD, -6402' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 83.5 62.6 87.0 84 25 65.5 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 7023' 84 13005 35 Carbonaceous Shale/Coal = grayish black mottled brownish black; firm; brittle in carbon shale to firm in coals; earthy mottled resinous luster; matte to striated texture; irregular to planar fracture along shale partings; visible bleeding gas from coal cuttings. E4ST: 7042' MD, -6919' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 86.1 24.8 67.1 30 3 9.4 Peaks Depth _ TG Cl C2 C3 C4I C4N C5I C5N 7086' 30 4262 50 Conglomerate/Conglomerate Sand =very light gray to light gray; clast size range very coarse upper to fine upper; angular to sub angular coarse grains to sub round medium to fine grains; poor to moderate 60 CANRIG Chevron WI TRADING BAY UNIT M-11 developed sphericity; very poorly sorted; polished coarse grains to impacted medium grains; sub mature nature; non to very weak silic cement; unconsolidated with some weakly consolidated clusters; very slight clay matrix; dominant grain support; arenaceous appearing as a sub gray wacke; becoming coarser with depth; good porosity and permeability; composed of 90% quartz, 10%chert with minor dark lithics. no show of oil. E4CT: 7173' MD, -6521' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 74.2 37.8 70.7 116 41 75.9 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 7194' 116 17597 113 12 Coal/Carbonaceous Shale= black to grayish black;firm; resinous; matte texture; sub conchoidal to irregular fracture; composed of lignite to sub bituminous coal; visible bleeding gas from cuttings. E5AST: 7214' MD, -6553' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 133.8 15.2 63.7 50 3 18.6 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 7307' 50 7942 98 14 Conglomerate Sand/Conglomerate=very light gray to light gray; clast size ranges from very coarse upper to medium lower; medium grains becoming coarse grained after 7240'; moderate developed sphericity; very poorly sorted polished and chipped textures; sub mature nature; no visible cement; unconsolidated with slight medium grain consolidated clusters weakly cemented; dominant grain support; no visible matrix material; composed of>90%quartz with secondary chert and trace dark gray lithics (argillite); good porosity and permeability; appears as a clean arenaceous sand; a sub greywacke in parts. E5ACT: 7354' MD, -6659' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 103.9 15.0 65.3 73 10 30.8 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 7375' 73 11174 58 20 Coal/Carbonaceous Shale= black to grayish black; firm; resinous; matte texture; sub conchoidal to irregular fracture; composed of lignite to sub bituminous coal; visible bleeding gas from cuttings 61 CANRIG Chevron 1111101 TRADING BAY UNIT M-11 E5BST: 7401' MD, -6694' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 115.3 5.4 72.5 34 7 19.5 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 7483' 34 6635 60 30 Sand = light to medium gray with light pinkish to greenish gray hues; lower medium to upper fine grains; rounded to sub-rounded sub-discoidal grains; well to very well sorted sands; sandstone fragments consolidated while sands unconsolidated; grain supported; quartz 80%, feldspars, argillite, micas; carbonaceous shale fragments with micro interbedded lignitic coal seams; fair permeability visually estimated. E5CCT: 7542' MD,-6797' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 84.2 42.4 71.2 193 18 117.9 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 7555' 193 37650 385 112 67 Coal/Carbonaceous Shale= black to grayish black;firm; resinous to earthy luster in carbon shale; matte texture; sub conchoidal to irregular fracture; composed of lignite to sub bituminous coal; visible bleeding gas from cuttings. E6CT: 7569' MD, -6816' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 84.8 47.4 75.5 171 33 106.7 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7569' 171 28607 269 112 28 Coal/Carbonaceous Shale = black to grayish black; firm; resinous; matte texture; sub conchoidal to irregular fracture; composed of lignite to sub bituminous coal; visible bleeding gas from cuttings. E7ST: 7578' MD, -6824' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 84.8 36.7 60.1 215 25 70.6 62 CANRIG Che,on ONO TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 7580' 215 22302 203 92 24 4 Sand = medium gray to dark gray; clast size ranges from medium lower to fine lower; moderate developed sphericity; sub round to rounded;well sorted; unconsolidated; grain supported; composed of 90% quartz with minor chert and various lithic fragments; good porosity and permeability; no show of oil fluorescence or oil cut. E7CT: 7607' MD, -6844' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 68.6 66.4 67.1 123 26 89.4 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 7616' 123 15445 122 63 16 12 Coal/Carbonaceous Shale= black to grayish black; firm; resinous to earthy luster in carbon shale; matte texture; sub conchoidal to irregular fracture; composed of lignite to sub bituminous coal; visible bleeding gas from cuttings. E9ST: 7670' MD, -6890' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 76.6 34.0 66.6 117 26 53.7 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 7701' 117 21286 268 56 11 Sand = medium gray to gray; clast size ranges from medium lower to fine lower; moderate developed sphericity; sub round to rounded; well sorted; unconsolidated; grain supported; composed of 90% quartz with minor chert and various lithic fragments; good porosity and permeability; no show of oil fluorescence or oil cut. Continued fine grain sand from E7. FCT: 7735' MD, -6936' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 68.8 67.9 68.2 125 18 85.7 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 7742' 125 22828 291 43 3 63 CANRIG Chevron 10401 TRADING BAY UNIT M-11 Carbonaceous Shale= dark gray with brownish gray to olive gray hues; hard and brittle;well indurated; irregular to conchoidal &splintery in some fracture; scaly: metallic luster; abrasive texture; prevalent degassing and coal present. FIST: 7769' MD, -6961' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 116.5 4.3 60.9 50 6 17.2 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 7780' 50 9287 120 15 Conglomerate/Conglomerate Sand = light gray to very light gray; clast size ranges from pebble/very coarse to medium lower; angular to sub angular bit impacted coarse grains to sub round medium grained matrix sands; poor to moderate developed sphericity; most grains equant; polish and chipped coarse grains to impacted medium grains; sub mature nature; no visible cement; unconsolidated with no visible matrix material; dominant grain supported; appears arenaceous and as a sub gray wacke; good porosity and permeability; composed of 80% quartz, 10% chert, 10% igneous, metamorphic, feldspar, greenstone and various lithic fragments; no show of oil fluorescence or oil cuts. FICT: 7925' MD, -7074' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 69.6 13.4 34.2 25 1 5.9 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 7925' 25 4433 53 14 No coal was noted in the samples. Only 20%very carbonaceous shale cuttings. Possible sweep sample with poor sample quality.Very small gas kick of 15 units over background. F2ST: 7954' MD, -7095' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 83.5 4.8 41.3 10 3 5.9 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 7956' 10 1791 Tuffaceous Siltstone= pinkish gray; poorly indurated; some clustered to clotted; gelatinous; slight mushiness; very hydrophilic; non to slight cohesiveness and adhesiveness; amorphous fracture and habit; clayey to colloidal textures; thick beds of gradational silts and clays. 64 CANRIG chQ IWO TRADING BAY UNIT M-11 F2CT: 8034' MD, -7153' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 46.9 5.1 31.2 46 6 17.9 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 8039' 46 8816 71 13 Coal/Carbonaceous Shale+ black mottled grayish black; firm becoming brittle in carbon shale; planar fracture in carbon shale to irregular to sub conchoidal fracture in coal; slight visible bleeding gas in coal fragments. F3ST: 8047' MD, -7162'SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 49 6 32 9 0 5 Peaks Depth TG Cl C2 C3 . C4I C4N C5I C5N 8057 9 1797 8 1 - - - - Conglomerate Sand =very light gray; clast size coarse upper to fine upper; sub angular to sub round; moderate developed sphericity; very poor sorting; polish, chip and impact texture sub mature nature; non to very weak silic cement; unconsolidated with few weakly consolidated sandstone clusters; dominant grain support; very slight hydrophilic clay matrix; composed of>90%quartz,with secondary chert and various lithic fragments; fair to good porosity and permeability; no oil. F3CT: 8132' MD, -7224' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 57 19 45 94 6 22 Peaks Depth TG Cl _ C2 C3 C4I C4N C51 C5N 8138 94 14858 57 - - - - - Coal/Carbonaceous Shale= brownish black to dark gray; brittle in carbon shale to hard in coals; bladed cuttings in carbon shale to hackly in coal; resinous to earthy textures; thin to lenticular bedding; no visible bleeding gas noted. F4ST: 8190' MD, -7266' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 80 13 50 21 5 13 65 CANRIG Chevron IOW TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 8235 21 4004 53 4 - - - - Conglomerate/Conglomeratic Sand = medium light to pinkish gray with pale yellowish brown sub hues; gravel sized clasts with lower to upper coarse sand matrix; main clasts are rounded to well rounded spherical to sub-discoidal, while matrix is angular to sub-angular; poor sorting overall, matrix is very well sorted; unconsolidated; matrix supported; immature; matrix-quartz 60%, mafics, feldspars, greenstone; sandstone clasts. F4CT: 8268' MD, -7323' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 67 42 57 187 18 79 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 8277 187 34528 474 82 - - - - Carbonaceous Shale= brownish black to dark gray in color; hard and brittle; moderate to well induration; bladed cuttings; abrasive and mottled; metallic to dull; lenticular bedding; highly angular quartz grains present. F5AST: 8295' MD, -7343' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average _ Maximum Minimum Average 69 20 53 118 18 42 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 8303 118 15557 127 101 - - - - Sand = light to medium gray with light olive gray hues; upper fine to lower medium spherical to sub- discoidal rounded to well rounded grains; unconsolidated; matrix is tuffaceous silts; grain supported; mature; quartz 80%, mafics, greenstone, feldspars, micas; angular coarse quartzite present along with non- indurated tuffaceous siltstones. F5BST: 8348' MD, -7381' SSTVD _ Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 72 12 54 44 11 19 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 8420 44 7532 37 12 - - - - Sand = light gray to medium gray; some olive gray;fine upper to medium lower; rounded to well rounded; unconsolidated; hydrophilic silty matrix; grain supported; mature to sub mature nature; composed of 80% 66 CANRIG Chevron WI TRADING BAY UNIT M-11 quartz with 20% chert, mafic, greenstone and various lithic fragments; angular coarse grains (bit impacted)fair to good porosity and permeability; no show of oil. F6ST: 8481' MD, -7477' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 46 21 36 15 9 14 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 8481 15 2764 26 6 - - - - Sandy Tuffaceous Siltstone= light to medium gray with pinkish to yellowish gray hues; poor induration; crumbly; massive habit; silty to gritty texture; dull to earthy luster; slightly cohesive; mildly adhesive; sand is interbedded being sub round to sub angular; moderate sphericity with sub discoidal grains; moderate to well sorted; unconsolidated quartz sand; no show of oil fluorescence or oil cut. F6CT: 8509' MD, -7498' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 72 33 67 187 18 120 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 8527 187 31427 391 235 - - - - Carbonaceous Shale/Coal=brownish black to olive black; brittle in carbon shale to hard in coal; platy habit in carbon shale to irregular in coal; resinous to earthy luster; thin to thick bedding. F7UST: 8533' MD, -7515' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 68 32 44 90 19 36 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 8533 90 15207 132 62 - - - - Sand= medium light gray to medium gray with light olive gray hues; moderate sphericity with sub discoidal grains; sub angular to sub round grains; moderate to well sorted; unconsolidated; grain supported; composed of 80% quartz, 20% chert, and various lithic fragments; fair porosity and permeability; no show of oil fluorescence or oil cut. F7MST: 8488' MD, -7555' SSTVD 67 CANRIG Chevron 1111011 TRADING BAY UNIT M-11 Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 39 16 33 35 8 17 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 8507 35 6234 110 3 - - - - No sand was in the samples, which consisted of sandy tuffaceous siltstone with some local thin beds of fine grain sand (<10%) F7CT: 8631' MD,-7586' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum _ Minimum Average 52 40 50 130 20 102 Peaks Depth TG C1 C2 C3 C4I C4N _ C51 C5N 8647 130 18153 168 28 - - - - Coal/Carbonaceous Shale = black mottled grayish black to brownish black at contacts; brittle in carbon shales to firm some hard in coals; resinous to striated earthy luster; matte to striated textures; irregular to sub planar fractures in carbon shale; composed of micro laminations of carbon shale to lignitic coal; no bleeding gas. F8AST: 8665' MD, -7611' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 44 40 43 69 44 66 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 8670 69 10065 76 - - - - - No sand was noted in the samples, which consisted of coal, carbonaceous shale and tuffaceous siltstone. F8BST: 8681' MD, -7622' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 45 11 32 45 13 18 Peaks Depth TG _ C1 C2 _ C3 C4I C4N C5I C5N 8700 45 5281 88 - - - - - 68 CANRIG Chevron 1111110 TRADING BAY UNIT M-11 Tuffaceous Siltstone= medium gray to light brownish gray; pale yellowish brown to grayish olives hues; easily friable; very poor induration; crumbly to crunchy; massive; mottled and gritty; dull and earthy; cohesive, mildly adhesive; micro inter-bedding of carbonaceous shale. F8CT: 8732' MD, -7660' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 58 15 49 101 21 40 Peaks Depth TG Cl C2 C3 C4I C4N C5l C5N 8775 101 19978 130 5 - - - - Carbonaceous Shale(8770' -8780') =grayish to brownish black, mottled; hard and brittle; moderate to well indurated; scalar and platy; abrasive; metallic to resinous; lenticular bedding. F9ST: 8791' MD, -7703' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum _ Minimum Average 66 26 56 100 30 53 Peaks Depth TG Cl C2 C3 C4I C4N C5l C5N 8800 100 21690 126 24 6 - - - Sand (8780'-8825') = medium light gray to medium gray; upper fine to lower medium grains; spherical to sub-discoidal sub-rounded to rounded grains; unconsolidated; grain supported; mature; quartz 85%, mafics,feldspars, greenstones. F9CT: 8823' MD, -7726' SSTVD Drill Rate(ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 55 14 46 187 10 56 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 8835 187 35209 157 28 13 - - - Carbonaceous Shale = brownish to olive gray with dark yellowish brown hues; hard and brittle; moderately induration; platy and scaly; abrasive; metallic to resinous; lenticular bedding; light degassing; plant fossils interbedded. 69 CANRIG Chew on IWO TRADING BAY UNIT M-11 F10CT: 8901' MD, -7782' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 78 32 67 218 28 165 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 8914 218 48569 234 21 - - - - Carbonaceous Shale = medium dark gray to dark gray with brownish to olive gray hues; mottled; hard and brittle; moderate to well induration; scaly to platy; abrasive; metallic to resinous; lenticular beds; degassing present. F11ST: 8933' MD, -7806' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 64 6 47 164 26 92 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8946 164 36551 176 28 - - - - Sand = light gray to medium gray with olive gray hues to greenish gray hues; clast size ranges from medium lower to fine upper; sub round to sub angular; moderate sphericity with sub discoidal grains; unconsolidated and grain supported; composed of 90%quartz, 10% chert and various lithic fragments; fair porosity and permeability; no show of oil fluorescence or oil cuts. F11CT: 8981' MD, -7841'SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 52 23 47 173 29 63 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 8986 173 38468 185 48 - - - - Carbonaceous Shale = medium dark gray to dark gray with brownish to olive gray hues; mottled; hard and brittle; moderate to well induration; scaly to platy; abrasive; metallic to resinous; lenticular beds; degassing present. F12CT: 8999' MD, -7854'SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 52 12 43 56 19 33 70 CANRIG Chevron OW TRADING BAY UNIT M-11 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 9031 56 12612 60 22 - - - - Carbonaceous Shale =dark gray to grayish black with olive to brownish gray hues; mottled surface; hard and brittle; moderate to well induration; scaly and platy; abrasive; metallic and resinous; lenticular scaly beds; degassing and plant fossils, F13BST: 9042' MD, -7884' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 60 43 54 118 21 74 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 9060 118 22878 110 49 - - - - Sand =very light gray; clast size medium lower to fine lower; sub round; moderate developed equant sphericity; moderate to well sorted; impact texture; mature nature; no visible cement; unconsolidated; appears arenaceous; no visible matrix material; composed of>95%quartz with chert and trace lithics; good porosity and good permeability; no show of oil. F13CT: 9072' MD, -7917' SSTVD Drill Rate(ft/hr Total Gas(units _ Maximum Minimum Average Maximum Minimum Average 55 10 44 47 9 25 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 9072 47 9158 22 10 - - - - Coal/Carbonaceous Shale = black mottled grayish black to brownish black at contacts; brittle in carbon shale to firm to hard in coals; earthy mottled resinous luster; hackly to irregular fracture in coal to sub planar fracture in carbonaceous shale; occurs as thin beds with visible out gassing noted in coals. F14AST: 9084' MD, -7915' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 47 10 37 36 4 19 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 9089 36 6534 41 12 - - - - Tuffaceous Siltstone/Sand (9120' -9190')= pinkish gray; poor-moderate induration crumbly to crunchy; stiff in parts; some grading to sand; sub earthy fracture; sub nodular habit; dull earthy luster; silty to sandy texture; grading to clean fine to medium sand as lenticular beds; some sandstone grading to siltstone; hydrophilic clays, sand and silts. 71 CANRIG Chevron ONO TRADING BAY UNIT M-11 F14BST: 9131' MD, -7950' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 44 43 43 29 11 19 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 9135 29 4404 90 14 - - - - Tuffaceous Siltstone/Sand = pinkish gray; poor to moderate induration; crumbly to crunchy; stiff in parts; some grading to very fine to fine sand; sub earthy fracture; sub nodular habit; dull earthy luster; silty to sandy texture; grading to clean fine to medium sand as lenticular beds; some sandstone grading to siltstone; hydrophilic clays, sands and silts overall. F14CST: 9154' MD, -7966' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 37 27 35 23 2 13 Peaks Depth TG Cl C2 C3 C4I C4N _ C51 C5N 9171 23 3871 153 32 - - - - Tuffaceous Siltstone/Sand = pinkish gray; poor to moderate induration; crumbly to crunchy; stiff in parts; some grading to very fine to fine sand; sub earthy fracture; sub nodular habit; dull earthy luster; silty to sandy texture; grading to clean fine to medium sand as lenticular beds; some sandstone grading to siltstone; hydrophilic clays, sands and silts overall. Continued samples from the F14 zone. F14CT: 9171' MD, -7978' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 46 26 37 59 9 27 Peaks Depth _ TG Cl C2 C3 C4I C4N C51 C5N 9177 59 11182 174 55 - - - - Coal/Carbonaceous Shale = black mottled grayish black to brownish black at contacts; brittle in carbon shale to firm to hard in coals; earthy mottled resinous luster; hackly to irregular fracture in coal to sub planar fracture in carbonaceous shale; occurs as thin beds with visible out gassing noted in coals 72 CANRIG Chevron IWO TRADING BAY UNIT M-11 F15AST: 9196' MD, -7996' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 37 17 28 11 6 10 Peaks Depth TG Cl C2 C3 C41 C4N C5I C5N 9208 11 1130 56 - - - - - Sand =very light gray; clast size medium lower to very fine upper; mean size fine grained; moderate to some well developed sphericity; moderate sorting; impact texture; sub mature to mature nature; no visible cement; unconsolidated; arenaceous; dominant grain support; >95% quartz; good porosity& permeability; no oil. F15BST: 9231' MD, -8021' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 90 12 40 25 7 14 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 9268 25 3683 49 - - - - - Sand =very light gray; clast size range medium lower to fine lower; sub angular to sub round; moderate developed sphericity; equant grains; moderate to well sorted with scattered coarse grains; impact texture; mature nature; non to very weak silic cement; unconsolidated; arenaceous; very slight clay/tuff matrix on scattered consolidated clusters; composed of>95% quartz with minor chert and trace lithic fragments; good porosity and good permeability; no oil indicators. F15CST: 9337' MD, -8098'SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 61 44 53 13 10 12 Peaks Depth TG Cl C2 C3 C4l C4N C5I C5N 9337 13 2460 18 18 - - - - Tuffaceous Siltstone(9330' -9390') = pinkish gray to pale yellowish brown; poor to moderate induration; brittle to stiff; crumbly to crunchy; slight to moderate cohesiveness; slightly adhesive sub earthy fracture; sub nodular habit; dull earthy luster; silty texture; thick gradational beds of tuffaceous silts and tuffaceous clays; scattered carbon shale and minor coal ay 9380'; trace ash. 73 CANRIG Chevron TRADING BAY UNIT M-11 F15CT: 9371' MD, -8122' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 52 19 40 49 5 16 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 9380 49 7777 337 - - - - - Coal/Carbonaceous Shale = black mottled grayish black to brownish black at contacts; brittle in carbon shale to firm to hard in coals; earthy mottled resinous luster; hackly to irregular fracture in coal to sub planar fracture in carbonaceous shale; occurs as thin beds with visible out gassing noted in coals F16ST: 9398' MD, -8142' SSTVD Drill Rate(ft/hr Total Gas (units _ Maximum Minimum Average Maximum Minimum Average 68 27 59 47 6 31 Peaks — Depth TG Cl C2 C3 C4I C4N C5I C5N 9425 47 9243 102 31 - - - - Sand (9410' -9490')=very light gray; clast size medium upper to fine lower scattered coarse grains; becoming coarse with depth; moderate developed sphericity; equant grain size; sub round moderate sorting; impacted texture; no visible cement; unconsolidated; dominant grain support; arenaceous; no visible matrix material; composed of>90%quartz secondary chert, trace lithics; good porosity and permeability; no oil grading to carbon shale/clay minor coal. F17ST: 9494' MD, -8211'SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average _ Maximum Minimum Average 57 9 41 16 3 9 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 9531 16 2386 32 - - - - - Sand/Tuffaceous Sandstone(9500' -9550')=very light gray to distinct pale yellow orange tuff matrix; clast medium upper to fine lower; moderate sphericity; equant grains; moderate sorting; impact texture sub mature nature; slight to moderate ash fall tuff matrix and cement; pore filling and a lithifying agent; grain support grading to matrix support with depth; composed of>95% quartz with various lithic fragments; fair porosity and fair to poorer permeability with depth; mineral fluorescence; no oil. 74 CANRIG Chevron iii IWO TRADING BAY UNIT M-11 GO1ST: 9547' MD, -8249' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 58 19 48 30 9 18 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 9550 30 5291 56 1 - - - - Sand/Tuffaceous Sandstone(9550' -9590')= light gray with pinkish yellowish gray hues; lower medium to upper fine clasts; spherical to sub-discoidal sub-angular to sub-rounded grains; moderately to well sorted sands; poor to moderate consolidation;tuffaceous matrix and cementing; grain supported sands and sandstones; mature; quartz 95%, mafics, feldspar, greenstone, other lithic fragments; mineral fluorescence; no oil. GO1CT: 9590' MD, -8280'SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 42 38 43 135 10 84 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 9603 135 25833 244 86 - - - - Carbonaceous Shale/Coal (9590' -9610') = brownish black to brownish gray; hard and brittle; well induration; scaly; abrasive and mottled; resinous to greasy; hydroids; micro coal inter-bedding with carbonaceous shale. GO2ST: 9622' MD, -8303' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 70 9 38 31 11 23 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 9658 31 5819 93 3 - - - - Sand/Tuffaceous Sandstone(9610'-9630') = medium light to light gray; upper to lower fine grains; rounded to sub rounded spherical clast; well sorted; moderately consolidated; grain support; 90% quartz, mafics, feldspar, greenstone and other lithic fragments. GO3ST: 9712' MD, -8368' SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 64 13 48 121 16 55 Peaks 75 CANRIG Cl* on TRADING BAY UNIT M-11 Depth TG C1 C2 C3 C4I C4N C5I C5N 9749 121 22940 201 64 - - - - Sand = light medium to medium gray with light olive gray hues; lower medium to upper fine grained; spherical to sub-discoidal sub-rounded to rounded grains; well sorted; unconsolidated; grain supported; mature; tuffaceous cementing, silt matrix; quartz 85%, mafics, feldspars, etc. G04ST: 9767' MD, -8408' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 65 32 58 133 26 62 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 9771 133 19357 248 65 - - - - Sand = light gray to medium gray with light olive gray hues; medium lower to fine upper; moderate sphericity with sub discoidal grains; sub rounded to rounded; well sorted; unconsolidated; grain and some matrix support; supported; mature nature; tuffaceous cement with weak silic cement; silt matrix; composed of 90%quartz, 10% chert and various lithic fragments; fair porosity and permeability; no oil fluorescence or oil cut. GO5ST: 9812' MD, -8441' SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 60 39 52 97 25 69 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 9851 97 18054 103 32 - - - - Sandy Tuffaceous Siltstone = medium gray to medium dark gray with light olive gray to grayish orange pink hues; easily friable to friable; poor to moderate induration; dense to crumbly; dull earthy luster; slightly cohesive and mildly adhesive; micro interbedding with carbonaceous shale grading to sand. Sands are medium lower to fine upper; moderate sphericity; to some sub prismoidal; sub angular to sub rounded grains; composed of 90% quartz, 10% chert and various lithic fragments. COAL39: 9916' MD, -8515' SSTVD Drill Rate(ft/hr) Total Gas(units Maximum Minimum Average Maximum Minimum Average 68 18 60 200 142 175 Peaks Depth TG Cl C2 C3 C41 C4N C51 C5N 9933 200 32058 678 166 74 - - - 76 CANRIG Chevron 111101 TRADING BAY UNIT M-11 Carbonaceous Shale =grayish black to brownish gray, mottled; hard and brittle; moderate to well induration; scaly and bladed; resinous to polished; micro interbedded coals. GIST: 9933' MD, -8528' SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 84 12 62 238 21 121 Peaks Depth TG Cl C2 C3 C4I C4N C51 C5N 9958 238 32058 1577 1255 808 22 Sand =very light gray; clast size medium upper to fine lower; sub round; moderate developed sphericity moderate sorting; impacted texture; mature nature; non to very weak silic cement; unconsolidated; no visible matrix material; dominant grain support; composed of>90%quartz; 80%+dull to moderate yellow even sample fluorescence; scattered very light brown oil stain; weak slow light blue green oil cut slow streaming opaque to moderate milky blue/green white cut; weak yellow green residue stain. G2ST: 10003' MD, -8578'SSTVD Drill Rate(ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 73 10 49 91 26 62 Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 10021 91 12772 775 749 574 176 Sand =very light gray; clast medium lower to very fine upper; sub round to sub angular; moderate to poor sphericity; moderate sorting; impact texture; sub mature to mature nature; non to weak silic cement; unconsolidated with slight consolidated clusters; very slight clay matrix; grain supported; composed of >90%quartz; good porosity; fair to good permeability; 80% dull yellow green even sample fluorescence; spotty faint light brown oil stain; dull blue green translucent fluorescent cut; slow develop oil cut to poor/fair blue green white;weak yellow green residue stain. G3ST: 10116' MD, -8659'SSTVD Drill Rate(ft/hr Total Gas(units Maximum Minimum Average Maximum Minimum Average 73 8 36 70 20 42 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 10133 70 11527 685 569 334 115 Sand =very light gray to light gray; clast medium upper to fine upper; sub round; moderate sphericity; moderate sorting; impact texture; sub mature nature; slight to moderate kaol matrix lithifying and pore filling agent unconsolidated with scattered sandstone clusters; grain support with secondary matrix support; composed of>90% quartz minor lithics; fair porosity and permeability; >80%dull yellow green 77 CANRIG Chevron 1111110 TRADING BAY UNIT M-11 even oil fluorescence; very faint spotty light brown oil stain; poor translucent dull yellow green oil cut; very faint yellow green residue stain. G4ST: 10166' MD, -8696'SSTVD Drill Rate(ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 40 3 28 62 15 33 Peaks Depth TG Cl C2 C3 C4I C4N C5I C5N 10220 62 10200 468 437 310 136 Sand = same as above but slightly coarser with no matrix; >80% dull yellow green even fluorescence; no visible oil stain; instant light blue white translucent slow to moderate streaming oil cut; slow develop to moderate translucent blue white cut; slight dull yellow green residue stain. 78 CANRIG Chevron 111110 TRADING BAY UNIT M-11 3.4. SAMPLING PROGRAM AND DSITRIBUTION Set Type and Purpose Interval Frequency Distribution Chevron North America E&P, Inc A Washed and Dried 480'to 10290' 30' 3800 Centerpoint Drive, Suite 100 5 boxes Anchorage,AK 99503 Attn: Francisco Castro Chevron North America E&P, Inc B Washed and Dried 480'to 10290' 30 3800 Centerpoint Drive, Suite 100 5 boxes Anchorage,AK 99503 Attn: Francisco Castro 79 CANRIG Chevron kW TRADING BAY UNIT M-11 4. DRILLING DATA 4.1. DAILY ACTIVITY SUMMARY November 3 2010: Finish building spud mud and circulate the drilling mud through the mud system, while looking for leaks. Perform all required safety drills and start to pick up the BHA and trip into the hole and clean out the conductor pipe to 435'. November 4th 2010: Finish drilling out the conductor pipe to 480'and pull out of the hole and change out the BHA from dumb iron to MWD tools. Commenced drilling formation drilling and sliding as needed as per the well plan taking surveys every thirty feet. November 5th 2010: Drill formation to 1440' and pump a high viscosity sweep and lay down the BHA and run in the hole and clean out. The maximum gas was 19 units. Prepare to rig up to run surface casing. November 6th 2010: Rig up to run 13 3/8"casing. Run casing to 470' and circulate the drilling mud. The maximum gas was 4 units. Run the casing to 1432' and circulate the drilling mud. Trip gas was 15 units. Continue to circulate the mud with decreasing gas from 15 units to one unit at midnight. November 7th 2010: Circulate the hole and land the casing. Cement the casing to the hole and rig down the cement equipment. Clean the rig floor and remove the diverters. Nipple down the BOPE and clean the mud pits. Begin building new drilling mud for open hole. November 8th 2010: Nipple up the BOPE and test the same. Prepare to pick up the drilling BHA and build the new drilling mud. November 9th 2010: Clean and clear the rig floor and pick up the MWD sources and load the same. Wash and ream from 340'to 418'. Tag cement and drill hard cement to 426'. Drill to 429' and trip in the hole to 1231'. Mad pass the hole and circulate and condition the hole. Trip gas was 20 units. Test the casing to 1500 psi. The test was good. Drill out the float from 1340'to 1345' and change out the drilling mud to 9.0 ppg and service the rig. November 10th 2010: Drill cement from 1416'to 1430' (shoe). Ream the hole to 1440'and drill formation from 1440'to 1460'. Trip gas was 70 units. Circulate the hole and perform the F.I.T. to 13.0 ppg. Drill formation to 1542' and change the shaker screens and drill to 1794'. Log the hole(Pressure Test)and drill to 2224'. Pumped a sweep with 50% increase in cuttings and tested the formation. Drill from 2224'to 3105' pumping sweeps to clean the hole. November 11th 2010: Drill the formation to 3434' and circulate and condition the hole. Flow checked the well (static) and started a wiper trip. The hole was tight at 3341', back ream to 3223'. The hole was tight at 3120', back ream out of the hole. Hole was tight at 3009', 2950' and 2843'to 2749'. Pumped out of the hole from 2274'to 2179'and tripped out from 2179'to 1421'. Circulate and condition the hole and monitor the well (static). Service the top drive and trip back in the hole to 3415'. Wash down to 3437'. Wiper gas was 57 units. Drill formation to 3500'. Service the top drive and drill to 3691'. Service the top drive and circulate the hole. 80 CANRIG Chevron kW TRADING BAY UNIT M-11 November 12th 2010: Finish servicing the top drive and drill formation to 3720'. Formation test the target sand and drill to 3786'. Formation test the target and drill to 3977'. Back ream the hole from 3977' to 3886' and formation test the target. Drill to 4071' and back ream the hole. Formation test the target and drill to 4163'. Log the hole with MWD and service the top drive. Drill formation to 4606' and circulate and condition the hole. The hole is taking mud losses at 2.5 b/h. Slowed the pump rates and pumped LCM oil to bottom. Let the LCM pill sit on bottom and stage the mud pumps from 300 gpm to 580 gpm with no mud losses. Drill formation from 4606'to 4620'. Work on the mud pump (plugged with LCM). November 139'2010: Drill from 4620'to 4734' and back ream the hole from 4734'to 4644'. Static test showed minimal mud losses. Circulate and condition the hole. The hole is taking mud losses and pumped a 30 bbl LCM pill to bottom. Trip out of the hole two stands and circulate and condition the hole above the LCM spotted pill at 4536'. Circulate and conditions the well three bottoms up and work the drill pipe from 4544'to 4455'. Trip out of the hole to 4265' and pressure test the formation. Trip out of the hole to 3886' (hole is static). Service the top drive and trip out of the hole to 3693'. Hole is swabbing, back ream from 3693'to 3317'. Circulate and condition the hole and work the drill pipe from 3422'to 3317'and back ream from 3317'to 2559'. The hole is swabbing with an over pull of 5,000. Back reamed from 2559'to 1424'. Circulate and condition the hole (bottoms up twice). Shakers are clean and flow check was good. Service the top drive and the well took 4.5 bbls/hr. Lay down the BHA and MWD sources. The hole took a 50 bbl loss while tripping out of the hole. November 14th 2010: Lay down the BHA and function test the BOPE. Pick up Bit#3 and the MWD tools and load the MWD sources. Trip in the hole to 1416' and circulate and condition the mud while testing the MWD tool. Static tested the hole. Service the top drive with a static fluid loss over 2.5 hours of 4 bbls. Trip in the hole to 4276' and tag up. Over pull was 160,wash and ream to 4734' and drill formation. Trip gas was 26 units. November 15th 2010: Drill formation to 5146' and pressure test the formation. Wash and ream from 5113'to 5202'. Drill formation to 5486' and formation test the target. Drill to 5682'with a fluid loss over 12 hours of 78 bbls(6.5 bbl/hr). Drill formation to 6310'. November 16th 2010: Drill formation to 6350' and mad pass the hole from 6470'to 6510'. Formation pressure test at 6448' and 6374'. Drill formation from 6530'to 6626'. Circulate and condition the hole. Rotate and reciprocate the hole from 6626'to 6536' and circulate bottoms up twice and pump a high viscosity sweep. Begin wiper trip and pull out of the hole to 6435'. Circulate and condition the hole and trip out on the elevators from 6435'to 5018'. Pressure test the formation from 4941'to 4924'. Trip out of the hole on elevators from 5018'to 4770'with 15K over pull with the hole swabbing and swelling.Wash and ream from 4770'to 4200'with a maximum gas reading pulling out of the hole of 151 units. November 17th 2010: Circulate and condition the hole and reciprocate the drill pipe from 4165 to 4070'. Trip in the hole and work through tight spots at 5458', 5635' and 5942' and wash and ream from 5942'to 5967'. Trip in the hole and ream 6536'to 6626'. Wiper gas was 285 units. Trip out of the hole from 6626'tight at 5774', 5424' and 5315'. Work back through tight spots and circulate and condition the hole and reciprocate from 4640'to 4544'and spot a LCM pill at 4544'. Trip out of the hole slowly on the elevators from 4070'to 3692'with a 50k over pull and swabbing. Wash and ream out of the hole from 3691'to 1416'. Circulate and condition the hole until the shakers are clean. Wait on weather(high winds). November 18th 2010: Wait on weather(high winds)and trip out of the hole from 1416' and stand back the HWDP. Lay down the BHA and remove the MWD source. Lay down the third party tools and 81 CANRIG Chevron 1111110 TRADING BAY UNIT M-11 clean the rig floor. Make up the wear ring and latch onto the same. Work the ring free and function test the rams. Rig up to run 9 5/8"casing and begin to run casing. November 19th 2010: Run 9 5/8" casing to 1428' and circulate and condition the drilling mud. The maximum gas was 1 unit. Run casing to 6234'and wash through a tight spot at 6324'. Wash down to 6618' and circulate and condition the hole. Trip gas was 38 units. Prepare to pump cement at midnight. November 20th 2010: Cement the 9 5/8"casing to the hole and rig down the cementing equipment. Move the cementing tools off the rig floor and prepare to test the BOPE. Function test the rams and make up the test plug and test joint. Change out the rams and fill the stack and choke with fluid. November 21st 2010: Test the BOPE and lay down the test tools and clean the rig floor. Load the new bit and stabs to the drill floor. Pick up BHA#5 and run in the hole. Test the MWD at 917' at 4 g/m. The maximum gas was 1 unit. Cut and slip new drill line and service the rig. Trip in the hole from 927'to 2634'and fill the drill pipe and trip in the hole from 2634'to 4151'. November 22nd 2010: Trip in the hole from 2634'to 4340' and fill the drill pipe. Run in the hole to the stage collar at 4366'. Drill out the stage collar from 4366'to 4368' and trip in the hole to 6480' and fill the drill pipe. Trip in the hole to the float collar at 6529' and circulate and condition the hole. Test the casing to 3000 psi and drill out the float collar from 6529'to 6533'. Drill the cement collar from 6533'to 6612'and circulate and condition the hole. Hold rig safety drills and then drill cement to 6618'. Circulate and condition the hole with trip gas showing 18 units. Drill formation to 6646'and run a FIT to 13.0 EMW. Commence drilling formation pumping high viscosity sweeps at every connection. November 23`d 2010: Drill formation to 8005', pumping high viscosity sweeps at every other connection, when needed. November 24th 2010: Drill formation to 8034' and circulate and condition the hole. Trip out of the hole to 6610'and circulate and condition the hole and monitor the well. Trip out of the hole to 832' and lay down the bit and MWD tools and secure the source. Lay down the rest of the BHA and service the top drive. Make up the new bit, BHA and MWD tools and run in the hole to 3620'. Circulate and condition the hole with 6 units of gas. Trip in the hole to 6780' and circulate and condition the hole. The maximum gas was one unit. Trip in the hole to 7945' and wash and ream to bottom. Trip gas was 202 units. Drill formation to 8039'. November 25th 2010: Drill formation to 8686' and trip out of the hole looking for a drill pipe wash out. Pull out of the hole to 6763'and lay down the washed out joint and pick up a new joint. Trip out of the hole to the shoe(6617')and monitor the well and service the top drive. November 26th 2010: Trip in the hole to 8608'. Wash and ream to 8686'. Wiper gas was 248 units. Drill formation to 9209' and test the formation with MWD. November 27th 2010: Drill formation to 9267' and work the drill pipe because of tight hole torque. Work the drill pipe from 9177'to 9267' and trip out of the hole to 6522'. Clean the rig floor and pick up the stage tools. Service the rig and install torque reducers on the drill pipe tripping in the hole with wiper gas of136 units and started to drill formation. 82 CANRIG Chevron 1111101 TRADING BAY UNIT M-11 November 28th 2010: Drill formation with no connection gases and pumping high viscosity sweeps with increased cuttings as the sweeps unload. November 29th 2010: Drill formation to 10290'. Circulate and condition the hole and pump a high viscosity sweep. Circulate and condition the hole. Begin a wiper trip to 9085' and circulate and condition the hole. Trip in the hole and wash the last stand to bottom with slight packing off at the bottom of the hole. Circulate a high viscosity sweep and a LCM pill. Wiper gas was 178 units and trip out of the hole to 832'. November 30th 2010: Stand back the HWDP and lay down the BHA, nuke source and tools. Clean the rig floor and service the rig. Rig up to run 7'casing and make up the shoe track and test the floats. Wait on high winds and begin to run 7"casing from 1080'to 1390'. December 1st 2010: Run liner from 1310'to 1921' and lay down one bad joint. Run in the hole to 3860' and make up the hanger assembly. Run in the hole to 4081' and then trip in the hole with 7" liner on 5" drill pipe to 6600'. Install the cement lines and make up the cement head. Trip in the hole with the liner on 5" drill pipe to 9900' and tag up with hole fill. Wash through the fill and run in the hole to 12080'. Circulate and condition the hole. Trip gas was 84 units. Hole torque and hole packing off occurring, continue to circulate and condition the hole. 83 CANRIG Tr co O r OD O (0 00 Tr CO r r CD (n h. co O r r` v (O Tr Orn N N- U) M r CO Tr O N- U) r- U) N Tr r- t? 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N O O WCCOO CCO 00) CO CSO N M O O O CO CO N- co co 0) 0) r r r O O O O O O O O O O W < O N M CV N (N C (N N NN N N N N N N N a r r r r \ /O CL / ƒ / § % § \ § / 3 ± 1-1-1 / \ z k } \ e 8 § 7 A» 6 a § R § 7 7 ■ `- w a on c 2 2 e N. ¢ 0 § k § k a % k % § 6 a w & a LU S \ 0) 0 § / \ / \0 o c m / § - b \ \ / o �\ # # c o ^tel ) / Nr. 2 2 Cl) f >< 2 § $ a 6 § w \ \ \ \ Z CO \ k CO k FA E '- § § / = o x CO CD LU X \ \ X § § 2 2 E § 0 0 0 0 0 0 I- I- I- I- \ 0 - - / q / ( N = q (Ni § a 8 a CO 0 n r Daily Report Page 1 of 1 CHEVRON M-11 DAILY WELLSITE REPORT El I EPOCH TRADING BAY UNIT REPORT FOR MENAPACE DATE 11/3/10 DEPTH 470.00000 PRESENT OPERATION CLEAN OUT CONDUCTOR TIME MIDNIGHT YESTERDAY SURFACE 24 HOUR FOOTAGE 0 CASING INFORMATION 32"@ 470' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 17.5" STC XR+60 PL9643 3X18, 1X14 SURFACE 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 470' MW 9.2 VIS 55 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 25 @ 435' 0 @ 150' 5 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 5 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE COLLECTION BEGINS UNDER 17.5"SURFACE CASING PRESENT LITHOLOGY DAILY ACTIVITY FINISH BUILDING SPUD MUD,CIRCULATE DRILLING MUD THROUGH MUD SYSTEM,PERFORM ALL SUMMARY REQUIRED DRILLS, PICK UP BHA AND TRIP IN THE HOLE AND CLEAN OUT CONDUCTOR PIPE TO 435' AT MIDNIGHT EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW DAILY COST$3525 DML, $1955 RW REPORT BY LEES F. BROWNE JR. r:i_.iii TN-----—4 _-a Cl-44�......`..%T.-.-.-1- A a—__XAii-- r----i % 11 PIPIn1n Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT E EPOCH M-11 REPORT FOR MENAPACE DATE Nov 04,2010 DEPTH 1002.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 480.00000 24 HOUR FOOTAGE 522' CASING INFORMATION CONDUCTOR @ 470' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 1 17.5" STC XR+60 PL9643 3X18, 1X14 SURFACE 4:19 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 396.6 @ 764.00000 8.8 @ 481.00000 157.8 207.13464 FT/HR SURFACE TORQUE 8283 @ 774.00000 1412 @ 861.00000 2688.5 4451.73389 AMPS WEIGHT ON BIT 22 @ 569.00000 0 @ 574.00000 10.9 8.02954 KLBS ROTARY RPM 67 @ 760.00000 SLIDE @ 921.00000 30.1 62.16639 RPM PUMP PRESSURE 1497 @ 989.00000 880 @ 481.00000 1210.3 1200.88623 PSI DRILLING MUD REPORT DEPTH 470' MW 9.2 VIS 52 PV 19 YP 32 FL 7.6 Gels 14/18/19 CL- 13000 FC 1/- SOL 3.2 SD 0.05 OIL - MBL 2.5 pH 10.2 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 72 @ 684.00000 0 @ 524.00000 22.9 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 13988 @ 684.00000 98 @ 524.00000 4420.3 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 1002.00000 0 @ 1002.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 1002.00000 0 @ 1002.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 1002.00000 0 @ 1002.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE(C-5) 0 @ 1002.00000 0 @ 1002.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAMPLE COLLECTION COMMENCES AT 1310'WITH SPOT SAMPLES ABOVE THE SZ8 COAL. PRESENT LITHOLOGY DAILY ACTIVITY FINISH DRILLING OUT CONDUCTOR PIPE TO 480', PULL OUT OF THE HOLE AND CHANGE OUT THE BHA, SUMMARY TRIP IN THE HOLE AND COMMENCE DRILLING FORMATION, DRILLING AND SLIDING AS NEEDED WITH SURVEYS EVERY 30',DRILL TO 1002'AT MIDNIGHT. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW DAILY COST$3525 DML, $1955 RW REPORT BY LEES F. BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT El EPOCH M-11 REPORT FOR MENAPACE DATE Nov 05,2010 DEPTH 1440.00000 PRESENT OPERATION PREP TO RUN 13 3/8"CASING TIME MIDNIGHT YESTERDAY 1002.00000 24 HOUR FOOTAGE 438' CASING INFORMATION CONDUCTOR @ 470' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1440' 17.18 264.05 1428.49 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 17.5" STC XR+60 PL9643 3X18, 1X14 470' 1440' 960' 9:04 CP/TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 389.1 @ 1175.00000 12.3 @ 1399.00000 125.4 57.40400 FT/HR SURFACE TORQUE 11539 @ 1090.00000 1977 @ 1305.00000 2022.9 AMPS WEIGHT ON BIT 30 @ 1391.00000 0 @ 1203.00000 12.7 10.00000 KLBS ROTARY RPM 68 @ 1339.00000 SLIDE @ 1070.00000 23.2 RPM PUMP PRESSURE 1605 @ 1120.00000 1115 @ 1222.00000 1287.5 PSI DRILLING MUD REPORT DEPTH 1440'(PIT#6) MW 9.5 VIS 47 PV 14 YP 29 FL 9.4 Gels 12/19/20 CL- 13500 FC 2/- SOL 7.4 SD 1.50 OIL - MBL 10.0 pH 9.0 Ca+ 1200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 145 @ 1429.00000 0 @ 1415.00000 25.1 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 26787 @ 1429.00000 101 @ 1415.00000 4819.5 CONNECTION GAS HIGH 0 ETHANE(C-2) 0 @ 1440.00000 0 @ 1440.00000 0.0 AVG 0 PROPANE(C-3) 0 @ 1440.00000 0 @ 1440.00000 0.0 CURRENT 0 BUTANE(C-4) 0 @ 1440.00000 0 @ 1440.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 1440.00000 0 @ 1440.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE,TUFFACEOUS SILTSTONE,SAND,COAL,CARBON SHALE PRESENT LITHOLOGY 1440'=50%TUFFACEOUS SILT,40%TUFFACEOUS CLAY, 10%SAND DAILY ACTIVITY DRILL FORMATION FROM 1002'TO 1440', PUMP A HIGH VIS SWEEP,LAY DOWN BHA AND RUN IN THE SUMMARY HOLE AND CLEAN OUT HOLE, MAXIMUM GAS WAS 19 UNITS,RIG UP TO RUN CASING. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW DAILY COST$3525 DML, $1955 RW REPORT BY LEES F. BROWNE JR. !`•1 //�-�T - ------ - --�- - -- 1 n _._._' 1' - _1 A 1---'--\1► T-- T 11 /G/r'►n1 /1 Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT El I EPOCH M-11 REPORT FOR MENAPACE DATE Nov 06,2010 DEPTH 1440.00000 PRESENT OPERATION CIRC w/CSG ON BOTTOM TIME 24 HOURS YESTERDAY 1440.00000 24 HOUR FOOTAGE 0' CASING INFORMATION CONDUCTOR @ 470' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1440' 17.18 264.05 1428.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 17.5" STCXR+60 PL9643 3X18,1X14 470' 1440' 960' 9:04 1-1-WT-A-E-1-NO TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 1440' MW 9.5 VIS 48 PV 14 YP 29 FL 9.6 Gels 12/18/20 CL- 14000 FC 1/- SOL 7.4 SD 1.50 OIL - MBL 7.5 pH 9.0 Ca+ 1280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 15 @ 1440' 0 @ TIH 4 CIRC TRIP GAS 15 @ 1440' CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG- PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 2 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 1440'=50%TUFFACEOUS SILT,40%TUFFACEOUS CLAY,10%SAND DAILY ACTIVITY RIG UP TO RUN 13 3/8"CASING,RUN CASING TO 470',CIRCULATE DRILLING MUD,MAX GAS 4 UNITS,RUN CASING TO TD AND SUMMARY CIRCULATE THE DRILLING MUD,TRIP GAS WAS 15 UNITS,CONTINUE TO CIRCULATE MUD AT MIDNIGHT WITH DECREASING GAS FROM 15 UNITS TO ONE UNIT AT MIDNIGHT. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$3525 DML, $1955 RW REPORT BY LEES F. BROWNE JR. file://C\Documents and Settings\EnochAdmin\Mv Documents\Mv Wells\C... 11/6/2010 Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT El EPOCH M-11 REPORT FOR MENAPACE DATE Nov 06,2010 DEPTH 1440.00000 PRESENT OPERATION NIPPLE DOWN BOPE,BUILD MUD TIME 24 HOURS YESTERDAY 1440.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1440' 17.18 264.05 1428.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N 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 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 2 @ CIRC 0 @ CIRC 1 TRIP GAS- CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG - PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100%CEMENT DAILY ACTIVITY RUN CASING TO 1432',CIRCULATE THE HOLE AND LAND THE CASING,CEMENT THE CASING TO THE HOLE, RIG DOWN CEMENT EQUIPMENT,CLEAN THE RIG FLOOR,REMOVE THE DIVERTERS,NIPPLE SUMMARY DOWN THE BOPE,CLEAN THE PITS,BUILD NEW DRILLING MUD. EPOCH PERSONNEL ON BROWNE, WINSLOW+ 2 DAILY$4425 DML, $1995 BOARD SC COST RW REPORT BY LEES F. BROWNE JR. file://C:\Documents and Settings\EpochAdmin\My Documents\... 11/7/2010 Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT El EPOCH M-11 REPORT FOR MENAPACE DATE Nov 08,2010 DEPTH 1440.00000 PRESENT OPERATION PICK UP DRLG BHA TIME 24 HOURS YESTERDAY 1440.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1440' 17.18 264.05 1428.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25" HTC MXL-1 X 5173843 3X16,1X14 1440' 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 1440' MW 9.1 VIS 50 PV 16 YP 13 FL 6.8 Gels 5/5/5 CL- 25000 FC SOL 2.2 SD 0.05 OIL - MBL 2.5 pH 9.5 Ca+ 1560 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS - @ - - @ - - TRIP GAS- CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG - PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG - PENTANE(C-5) @ @ HYDROCARBON SHOWS NO MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100%CEMENT DAILY ACTIVITY NIPPLE UP BOPE AND TEST THE SAME, PREP TO PICK UP DRILLING BHA AND BUILD DRILLING SUMMARY MUD EPOCH PERSONNEL ON BROWNE, WINSLOW + 2 DAILY$4425 DML, $1995 BOARD SC COST RW REPORT BY LEES F. BROWNE JR. fi1P•//C•\Tlnrrnmatnte and .Cattinae\P-nnrh Admin\Mv 1lnriimentc\ 11 /R/2n1 n Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT El EPOCH M-11 REPORT FOR MENAPACE DATE Nov 09,2010 DEPTH 1440.00000 PRESENT OPERATION DRILL OUT CEMENT TIME 24 HOURS YESTERDAY 1440.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13 3/8"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1440' 17.18 264.05 1428.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25 HTC MXL-1X 5173843 3X16, 1X14 1440' 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 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 20 @ CEMENT 0 @ CEMENT 1 TRIP GAS 20 CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG - PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 1 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100%CEMENT CLEAN AND CLEAR THE RIG FLOOR, DRILL STAGE COLLAR,PICK UP NUKES AND LOAD,WASH AND REAM DAILY FROM 340'TO 418',TAG CEMENT AND DRILL HARD CEMENT TO 426',DRILL TO 429'AND TRIP IN THE HOLE ACTIVITY TO 1231',MAD PASS THE HOLE AND CIRCULATE AND CONDITION THE HOLE,TRIP WAS 20 UNITS,TEST SUMMARY THE CASING TO 1500 PSI,TEST WAS GOOD,DRILL OUT FLOAT FROM 1340'TO 1345',CHANGE OUT THE DRILL MUD TO 9.0 PPG,SERVICE THE RIG. EPOCH PERSONNEL ON BROWNE, WINSLOW + 2 DAILY$4425 DML, $1995 BOARD SC COST RW REPORT BY LEES F. BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT U EPOCH M-11 REPORT FOR MENAPACE DATE Nov 10,2010 DEPTH 3105.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 1440.00000 24 HOUR FOOTAGE 1665' CASING INFORMATION 13 3/8"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25" HTC MXL-1X 5173843 3X16, 1X14 1440' 12:30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 699.6 @ 1795.00000 7.7 @ 1543.00000 175.1 169.57935 FT/HR SURFACE TORQUE 10272 @ 3086.00000 2761 @ 1469.00000 6499.4 7620.28760 AMPS WEIGHT ON BIT 52 @ 1986.00000 1 @ 1469.00000 20.8 26.95527 KLBS ROTARY RPM 173 @ 2849.00000 0 @ 1796.00000 130.9 169.85779 RPM PUMP PRESSURE 1477 @ 2746.00000 1 @ 1795.00000 1276.8 1439.47107 PSI DRILLING MUD REPORT DEPTH 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 575 @ 1830.00000 0 @ 2056.00000 134.9 TRIP GAS 70 CSG CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 91614 @ 2951.00000 13 @ 2056.00000 16955.7 CONNECTION GAS HIGH 6 ETHANE(C-2) 0 @ 3105.00000 0 @ 3105.00000 0.0 AVG 1 PROPANE(C-3) 0 @ 3105.00000 0 @ 3105.00000 0.0 CURRENT 1 BUTANE(C-4) 0 @ 3105.00000 0 @ 3105.00000 0.0 CURRENT BACKGROUND/AVG 100 PENTANE(C-5) 0 @ 3105.00000 0 @ 3105.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAY,TUFFACEOUS SILT,COAL,CARBON SHALE,SAND,SANDSTONE, CONGLOMERATE SAND PRESENT 3100'=30%CABONACEOUS SHALE,50%TUFFACEOUS CLAY,20%TUFFACEOUS SILT LITHOLOGY DRILL CEMENT FROM 1416 TO 1430'(SHOE),REAM HOLE TO 1440', DRILL FROM 1440'TO 1460',TRIP GAS DAILY 70 UNITS,CIRCULATE THE HOLE, PERFORM FIT TO 13.00 PPG,DRILL FORMATION TO 1542',CHANGE ACTIVITY SHAKER SCREENS,DRILL TO 1794',LOG HOLE WITH PRESSURE TEST, DRILL TO 2224', PUMP SWEEPS SUMMARY WITH 50%INCREASE IN CUTTINGS,TEST FORMATION WITH SCHLUMBERGER,DRILL FROM 2224 TO 3105, PUMPING SWEEPS TO CLEAN THE HOLE. EPOCH PERSONNEL ON BROWNE, WINSLOW + 2 DAILY$4425 DML, $1995 BOARD SC COST RW REPORT BY A 1 1ii ni'ni n Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT Ell EPOCH M-11 REPORT FOR SHANE HAUCK DATE Nov 11,2010 DEPTH 3691.00000 PRESENT OPERATION WORK ON TOP DRIVE TIME 24 HOURS YESTERDAY 3105.00000 24 HOUR FOOTAGE 586 CASING INFORMATION 13 3/8"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3257.75' 24.82 188.68 3050.63 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25" HTC MXL-1 X 5173843 3X16,1X14 1440 18:48 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 543.3 @ 3437.00000 12.9 @ 3674.00000 139.4 99.04259 FT/HR SURFACE TORQUE 14078 @ 3343.00000 6157 @ 3123.00000 9080.0 10799.75977 AMPS WEIGHT ON BIT 42 @ 3208.00000 0 @ 3437.00000 31.5 32.72260 KLBS ROTARY RPM 181 @ 3239.00000 130 @ 3675.00000 166.4 166.56104 RPM PUMP PRESSURE 1557 @ 3595.00000 993 @ 3472.00000 1442.8 1499.53943 PSI DRILLING MUD REPORT DEPTH 2180' MW 9.2 VIS 51 PV 14 YP 15 FL 5.5 Gels 5/6/7 CL- 33000 FC 1/- SOL 3.4 SD - OIL 2.0/92.0 MBL 2.0 pH 8.8 Ca+ 880 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 347 @ 3234.00000 2 @ 3691.00000 62.5 TRIP GAS- CUTTING GAS @ @ WIPER GAS 57 @ 3434' CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 67258 @ 3233.00000 721 @ 3503.00000 11862.7 CONNECTION GAS HIGH 0 ETHANE(C-2) 60 @ 3383.00000 0 @ 3401.00000 2.4 AVG 0 PROPANE(C-3) 57 @ 3383.00000 0 @ 3401.00000 1.5 CURRENT 0 BUTANE(C-4) 0 @ 3691.00000 0 @ 3691.00000 0.0 CURRENT BACKGROUND/AVG 5 PENTANE(C-5) 0 @ 3691.00000 0 @ 3691.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND,SANDSTONE,CONGLOMERATE SAND,CONGLOMERATE,COAL,CARBON SHALE,SILT,CLAY PRESENT LITHOLOGY 3691'=30%CONGLOMERATE SAND,30%SAND,30%TUFFACEOUS CLAY,10%CONGLOMERATE DRILL FORMATION TO 3434',CIRCULATE AND CONDITION THEHOLE,FLOW CHECK WELL=STATIC,START WIPER TRIP,HOLE DAILY TIGHT AT 3341',BACK REAM TO 3223',HOLE TIGHT AT 3120'BACK REAM OUT,HOLE IS TIGHT AT 3009',2950',2843-2749',PUMP OUT ACTIVITY OF THE HOLE FROM 2274-2179',TRIP OUT FROM 2179 TO1421'(SHOE),CIRCULATE AND CONDITION THE HOLE,MONITOR THE SUMMARY WELL(STATIC),SERVICE THE TOP DRIVE,TRIP IN THE HOLE TO 3415'WASH DOWN TO 3437',WIPER GAS WAS 57 UNITS,DRILL FORMATION TO 3500',SERVICE THE TOP DRIVE,DRILL TO 3691'SERVICE THE TOP DRIVE,CIRCULATE THE HOLE. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+ 2 SC DAILY COST$4425 DML, $1995 RW REPORT BY LEES F. BROWNE JR. c:1,..ii(Ar.,-........,,,-+, .,.,a c.,++;..,.�Vz',..,.,.i,A -1.--;,-AAAi‘, r'1,,,.11v,o�+AAITT 7 \1Tv11A 1 1 /1 1 /1/11(1 Daily Report Page 1 of 1 CHEVRON PI EPOCH DAILY WELLSITE REPORT M-11 REPORT FOR LOFT/HAUCK DATE Nov 12,2010 DEPTH 4620.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 3691.00000 24 HOUR FOOTAGE 929' CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4205.67 9.58 118.34 3961.18 SURVEY DATA 3826.22 12.05 165.64 3587.32 3731.42 14.73 171.73 3495.10 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETSIN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25" HTCMXL-1X 5173843 3X16,1X14 1440 32 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 638.8 @ 3883.00000 5.5 @ 4608.00000 94.5 19.45284 FT/HR SURFACE TORQUE 15613 @ 4310.00000 8573 @ 3720.00000 11000.9 12162.75488 AMPS WEIGHT ON BIT 82 @ 4073.000005 @ 4247.00000 31.4 18.77232 KLBS ROTARY RPM 175 @ 4325.00000 117 @ 4477.00000 160.3 120.08318 RPM PUMP PRESSURE 1665 @ 4603.00000 780 @ 4609.00000 1480.5 802.36920 PSI DRILLING MUD REPORT DEPTH 3200' MW 9.2 VIS 47 PV 13 YP 21 FL 6.0 Gels 8/9/10 CL- 2080 FC 1/- SOL 5.3 SD 0.05 OIL 2/92.4 MBL 2.5 pH 7.8 Ca+ 1920 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 392 @ 4453.00000 2 @ 4585.00000 65.1 TRIP GAS - CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 43918 @ 4363.00000 355 @ 4585.00000 9907.8 CONNECTION GAS HIGH 3 ETHANE(C-2) 430 @ 4218.00000 0 @ 4029.00000 46.5 AVG 0-1 PROPANE(C-3) 56 @ 4364.00000 0 @ 4338.00000 1.6 CURRENT 0 BUTANE(C-4) 0 @ 4620.00000 0 @ 4620.00000 0.0 CURRENT BACKGROUND/AVG 50 PENTANE(C-5) 0 @ 4620.00000 0 @ 4620.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND,CONGLOMERATE SAND,CONGLOMERATE,COAL,CARBON SHALE,TUFFACEOUS SILT,TUFFACEOUS CLAY,ASH PRESENT LITHOLOGY 4620'-CONGLOMERATE SAND 60%,SAND 20%,CONGLOMERATE 10%,TUFFACEOUS CLAY 10% SERVICE THE TOP DRIVE,DRILL FROM 3691 TO 3720',FORMATION TEST,DRILL TO 3786',FORMATION TEST,DRILL TO 3977',BACK REAM HOLE FROM 3977 TO 3886', DAILY ADFORMATION TEST,DRILL TO 4071',BACK REAM HOLE,FORMATION TEST,DRILL TO 4163',LOG HOLE AND SERVICETHE TOP DRIVE,DRILL FORMATION TO 4606',CIRCULATE SUMMARY AND CONDITION THE HOLE,HOLE TAKING LOSSES AT 2.5 B/H,SLOW PUMP RATES,PUMP LCM PILL ON BOTTOM,LET SIT,STAGE PUMPS FROM 300 GPM TO 580 GPM WITH NO LOSSES,DRILL FROM 4606 TO 4620',WORK ON MUD PUMP(LCM) EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4425 DML, 1995 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 2 CHEVRON DAILY WELLSITE REPORT PI EPOCH M-11 REPORT FOR LOFT/HAUCK DATE Nov 13,2010 DEPTH 4734.00000 PRESENT OPERATION LAY DOWN BHA&BIT#2 TIME 24 HOURS YESTERDAY 4620.00000 24 HOUR FOOTAGE 114 CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4734 4482.05 4584.83 8.67 56.44 4334.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12.25" HTC MXL-1X 5173843 3X16,1X14 1440 4734 3294' 34:09 PR DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 107.4 @ 4725.00000 19.5 @ 4620.00000 56.8 21.45347 FT/HR SURFACE TORQUE 19298 @ 4651.00000 12162 @ 4620.00000 15873.3 14437.80957 AMPS WEIGHT ON BIT 36 @ 4732.00000 17 @ 4653.00000 30.0 33.27148 KLBS ROTARY RPM 175 @ 4677.00000 120 @ 4620.00000 164.8 155.66483 RPM PUMP PRESSURE 1652 @ 4699.00000 802 @ 4620.00000 1599.9 1571.01526 PSI DRILLING MUD REPORT DEPTH 4734' MW 9.2 VIS 49 PV 16 YP 16 FL 7.0 Gels 10/14/18 CL- 21000 FC 1/- SOL 3.3 SD 0.10 OIL 2.0/93.0 MBL 7.5 pH 8.0 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 51 @ 4624.00000 2 @ 4730.00000 24.1 TRIP GAS- CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 9458 @ 4624.00000 413 @ 4730.00000 4374.5 CONNECTION GAS HIGH 0 ETHANE(C-2) 17 @ 4622.00000 0 @ 4643.00000 1.7 AVG 0 PROPANE(C-3) 8 @ 4622.00000 0 @ 4643.00000 0.8 CURRENT 0 BUTANE(C-4) 0 @ 4734.00000 0 @ 4734.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 4734.00000 0 @ 4734.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND,CONGLOMERATE SAND,SANDSTONE,CONGLOMERATE.TUFFACEOUS SILT,TUFFACEOUS CLAY PRESENT 4734'=10%SANDSTONE,40%SAND,30%CONGLOMERATE SAND, 10%CONGLOMERATE, 10% LITHOLOGY TUFFACEOUS CLAY DRILL FROM 4620-4734',BACK REAM FROM 4734 TO 4644',STATIC TEST=MINIMAL LOSSES,CIRCULATE AND CONDITION THE HOLE, HOLE TAKING MUD LOSSES PUMP 30 BBL/LCM PILL ON BOTTOM,TRIP OUT OF THE DAILY HOLE TWO STANDS,CIRCULATE AND CONDITION ABOVE THE LCM SPOTTED PILL @ 4536',CIRCULATE AND ACTIVITY CONDITION THE WELL THREE BOTTOM'S UP AND WORK THE DRILL PIPE FROM 4544 TO 4455',TRIP OUT OF SUMMARY THE HOLE TO 4265'AND PRESSURE TEST THE FORMATION,TRIP OUT OF THE HOLE TO 3886'(HOLE IS OK), SERVICE THE TOP DRIVE,TRIP OUT OF THE HOLE TO 3693'HOLE IS SWABBING, BACK REAM FROM 3693 TO 3317',CIRCULATE AND CONDITION THE HOLE,WORK THE DRILL PIPE FROM 3422-3317'AND BACK REAM FROM 3317 TO 2559', HOLE IS SWABBING,OVERPULLED 5K,BACK REAM 2559 TO 1424'CIRCULATE AND T1lP•f rl-Vn tnii ' iarite Qr 11 ffitl(Yc\Hr nr•IN A Amin\ /lir i',m Y1tc\ 1 1 /1 2/1(11 (1 Daily Report Page 2 of 2 CONDITION BOTTOM'S UP TWICE,SHAKERS ARE CLEAN, FLOW CHECK-OK,SERVICE THE TOP DRIVE, WELL TOOK 4.5 BBLS/HR,LAY DOWN THE BHA AND NUKE SOURCE, HOLE TOOK 50 BBL LOSS WHILE TRIPPING OUT OF THE HOLE. EPOCH PERSONNEL ON BROWNE, WINSLOW + 2 DAILY$4425 DML, $1995 BOARD SC COST RW REPORT BY LEES F. BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT U EPOCH M-11 REPORT FOR LOFT/HAUCK DATE Nov 14,2010 DEPTH 5019.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 4734.00000 24 HOUR FOOTAGE 285' CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4734 4482.05 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25" STC MDSi616 JE0684 6X13 4734' 3 2 12.25" HTC MXL-1X 5173843 3X16,1X14 1440 4734 3294 34:09 1-2-WT-A-E-2-RG PR DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 213.6 @ 4755.00000 18.3 @ 4821.00000 116.6 87.16074 FT/HR SURFACE TORQUE 20313 @ 4853.00000 13290 @ 4742.00000 15842.0 14781.37891 AMPS WEIGHT ON BIT 33 @ 4734.00000 0 @ 4987.00000 5.5 0.00000 KLBS ROTARY RPM 171 @ 4829.00000 77 @ 4853.00000 157.5 158.17912 RPM PUMP PRESSURE 1591 @ 4897.00000 1107 @ 4776.00000 1517.6 1552.11169 PSI DRILLING MUD REPORT DEPTH 4734 MW 9.2 VIS 49 PV 16 YP 16 FL 7.0 Gels 10/14/18 CL- 21000 FC 1/- SOL 3.3 SD 0.10 OIL 2.0/93.0 MBL 7.5 pH 8.0 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 277 @ 4779.00000 1 @ 4982.00000 83.2 TRIP GAS 26 @ 4734' CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 39104 @ 4919.00000 202 @ 4982.00000 10133.1 CONNECTION GAS HIGH 0 ETHANE(C-2) 366 @ 4919.00000 0 @ 4829.00000 79.5 AVG 0 PROPANE(C-3) 83 @ 4950.00000 0 @ 4982.00000 10.5 CURRENT 0 BUTANE(C-4) 0 @ 5019.00000 0 @ 5019.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE(C-5) 0 @ 5019.00000 0 @ 5019.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE SAND,CONGLOMERATE,SAND,SANDSTONE,TUFFACEOUS SILT,TUFFACEOUS CLAY,COAL, CARBON SHALE PRESENT 5010'=70%TUFFACEOUS CLAY,30%TUFFACEOUS SILT LITHOLOGY DAILY LAY DOWN THE BHA,FUNCTION TEST THE BOPE,PICK UP BHA AND MAKE UP BIT#3,PICK UP MWD TOOLS AND LOAD ACTIVITY Y NUKES,TRIP IN THE HOLE TO 1416',CIRCULATE AND CONDITION THE MUD AND TEST MWD,STATIC TEST THE HOLE, SUMMARY SERVICE THE TOP DRIVE,STATIC FLUID LOSS OVER 2.5 HOURS WAS 4 BBLS,TRIP IN THE HOLE TO 4276 AND TAG UP, OVER PULL AT 160 LBS,WASH AND REAM TO 4734 AND DRILL FORMATION,TRIP GAS WAS 26 UNITS. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4425 DML, $1995 RW REPORT BY LEES F. BROWNE JR. �:i //el TN A 1 1 /1 A i")n1I 11 Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT HI EPOCH M-11 REPORT FOR LOFT/HAUCK DATE Nov 15,2010 DEPTH 6310.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 5019.00000 24 HOUR FOOTAGE 1291' CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5812.58 19.18 33.3 5534.17 SURVEY DATA 5717.62 17.14 30.66 5443.94 5622.78 14.62 31.26 5352.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25" STC MDSi616 JE0684 6X13 4734' 19:34 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 195.2 @ 5521.00000 6.3 @ 5524.00000 91.6 67.71754 FT/HR SURFACE TORQUE 21557 @ 5792.00000 12720 @ 5239.00000 17701.8 18957.10547 AMPS WEIGHT ON BIT 13 @ 5311.00000 0 @ 5796.00000 6.7 9.87870 KLBS ROTARY RPM 171 @ 5239.00000 0 @ 5792.00000 1192 114.95584 RPM PUMP PRESSURE 1818 @ 5584.00000 1216 @ 5304.00000 1659.4 1639.45935 PSI DRILLING MUD REPORT DEPTH 5032' MW 9.3 VIS 46 PV 13 YP 20 FL 6.8 Gels 7/9/11 CL- 21000 FC 1/- SOL 4.3 SD 0.10 OIL 2/92 MBL 10.0 pH 8.0 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 453 @ 5368.00000 2 @ 5482.00000 81.7 TRIP GAS- CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 153501 @ 5290.00000 429 @ 5482.00000 13062.8 CONNECTION GAS HIGH 3 ETHANE(C-2) 779 @ 5318.00000 0 @ 6028.00000 61.2 AVG 0-1 PROPANE(C-3) 69 @ 6069.00000 0 @ 6158.00000 2.1 CURRENT 0 BUTANE(C-4) 0 @ 6310.00000 0 @ 6310.00000 0.0 CURRENT BACKGROUND/AVG 22 PENTANE(C-5) 0 @ 6310,00000 0 @ 6310.00000 0,0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND,SANDSTONE,CONGLOMERATE SAND,CONGLOMERATE,TUFFACEOUS SILTSTONE,TUFFACEOUS CLAYSTONE,COAL,CARBON SHALE AND CARBON CLAY PRESENT LITHOLOGY 6310'=COAL 50%CARBONACEOUS SHALE/CLAY 50% DAILY ACTIVITY DRILL FORMATION TO 5146',OPEN HOLE LOG AND TEST FORMATION,WASH AND REAM 5113'TO 5202',DRILL FORMATION TO 5486',OPEN HOLE LOG AND TEST SUMMARY FORMATION,DRILL TO 5682',FLUID LOSS 12 HOURS WAS 78 BBLS/6.5 BBLS/HOUR,DRILL FORMATION TO 6310' EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4425 DML,$1995 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT Ell EPOCH .11 REPORT FOR LOFT/HAUCK DATE Nov 15,2010 DEPTH 6625.00000 PRESENT OPERATION WIPER TRIP TIME 24 HOURS YESTERDAY 6310.00000 24 HOUR FOOTAGE 315' CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6625 6166.81 SURVEY DATA 6567 36.16 43.89 6119.99 6466 34.04 44.11 6117.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25" STC MDSi616 JE0684 6X13 4734 6525 1891 26:20 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 113.4 @ 6479.00000 10.3 @ 6520.00000 60.4 59.19106 FT/HR SURFACE TORQUE 23127 @ 6615.00000 16668 @ 6454.00000 19350.2 18608.80469 AMPS WEIGHT ON BIT16 @ 6341.00000 0 @ 6522.00000 7.6 2.40212 KLBS ROTARY RPM 165 @ 6543.00000 0 @ 6342.00000 128.0 127.50138 RPM PUMP PRESSURE 1792 @ 6417.00000 1404 @ 6434.00000 1708.2 1706.66736 PSI DRILLING MUD REPORT DEPTH 5032' MW 9.3 VIS 46 PV 13 YP 20 FL 6.8 Gels 7/9/11 CL- 21000 FC 1/- SOL 4.3 SD 0.10 OIL 2.0/92.0 MBL 10.0 pH 8.0 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 271 @ 6431.00000 1 @ 6521.00000 30.7 TRIP GAS CUTTING GAS @ @ WIPER GAS 151 PULLING OUT CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 35513 @ 6430.00000 291 @ 6521.00000 5005.2 CONNECTION GAS HIGH 2 ETHANE(C-2) 370 @ 6430.00000 0 @ 6550.00000 31.2 AVG 0-1 PROPANE(C-3) 46 @ 6430.00000 0 @ 6474.00000 4.9 CURRENT 2 BUTANE(C-4) 0 @ 6625.00000 0 @ 6625.00000 0.0 CURRENT BACKGROUND/AVG 20 PENTANE(C-5) 0 @ 6625.00000 0 @ 6625.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE SAND,CONGLOMERATE,SAND,TUFFACEOUS SANDSTONE,TUFFACEOUS CLAY,TUFFACEOUS SILT,CARBON SHALE,COAL PRESENT LITHOLOGY 6625'=TUFFACEOUS SILTSTONE 50%,TUFFACEOUS CLAY 40%CARBONACEOUS CLAY/SHALE 10% DRILL FORMATION TO 6530',MAD PASS THE HOLE FROM 6470-6510',FORMATION PRESSURE TEST AT 6448'AND 6374',DRILL FORMATION FROM 6530 TO 6626'(TD),CIRCULATE DAILY AND CONDITION THE HOLE(ROTATING AND RECIPROCATING)FROM 6626-6536',CIRCULATE BOTTOMS UP TWICE AND PUMP HIGH VIS SWEEPS;BEGIN WIPER TRIP AND PULL ACTIVITY OUT OF THE HOLE TO 6435',CIRCULATE AND CONDITION THE HOLE,TRIP OUT ON THE ELEVATORS FROM 6435-5018',PRESSURE TEST THE FORMATION 4941-4924',TRIP OUT SUMMARY OF THE HOLE ON ELEVATORS FROM 5018'-4770'WITH 150K OVERPULL WITH THE HOLE SWABBING AND SWELLING;WASH AND REAM FROM 4770-4200',MAXIMUM GAS PULLING OUT OF THE HOLE TO 4200'WAS 151 UNITS. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$3525 DML,$1955 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT PI } } C}-J .1 REPORT FOR LOFT/HAUCK DATE Nov 17,2010 DEPTH 6626.00000 PRESENT OPERATION WAIT ON WEATHER TIME 24 HOURS YESTERDAY 6626.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6626 6166.81 ' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25" STC MDSi616 JE0684 6X13 4734 6626 1892 26:20 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 6626 MW 9.3 VIS 45 PV 14 YP 20 FL 4.0 Gels 8/10/12 CL- 19000 FC 1/- SOL 5.0 SD 0.25 OIL 1.5/92.0 MBL 8.5 pH 8.5 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 285 @ WIPER GAS 1 @ TOH 2-5 TOOH TRIP GAS - CUTTING GAS @ @ WIPER GAS 285 @ 4626' CHROMATOGRAPHY(ppm) SURVEY - METHANE(C-1) @ @ CONNECTION GAS HIGH - ETHANE(C-2) @ @ AVG - PROPANE(C-3) @ @ CURRENT - BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 4626'=50%TUFFACEOUS CLAYSTONE,40%TUFFACEOUS CLAY,10%COAL/CARBONACEOUS SHALE CIRCULATE AND CONDITION THE HOLE,RECIPROCATE THE DRILL PIPE 4165-4070',TRIP IN THE HOLE AND WORK THROUGH TIGHT SPOTS DAILY @° 5458',5635',5942',WASH AND REAM 5942-5967',TRIP IN THE HOLE AND REAM 6536'-6626',WIPER GAS WAS 285 UNITS,TRIP OUT OF THE ACTIVITY HOLE 6626-4640',HOLE WAS TIGHT @ 5774',5434'AND 5315',WORK BACK THROUGH TIGHT SPOTS AND CIRCULATE AND CONDITION THE SUMMARY HOLE AND RECIPROCATE 4640-4544'AND SPOT LCM PILL @ 4544',TRIP OUT OF THE HOLE SLOW ON THE EKLEVATORS 4070-36921'WITH 50K OVERPULL AND SWABBING,WASH AND REAM OUT OF THE HOLE 3691-1416',CIRCULATE AND CONDITION THE HOLE UNTIL THE SHAKERS ARE CLEAN,WAIT ON WEATHER(HIGH WINDS) EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW DAILY COST $4095 DML, $1955 DML REPORT BY LEES F. BROWNE JR. Daily Report Page 1 of 1 CHEVRON n EPOCH DAILY WELLSITE REPORT M-11 REPORT FOR LOFT/LESLIE DATE Nov 18,2010 DEPTH 6626.00000 PRESENT OPERATION RUNNING95/8"CASING TIME 24 HOURS YESTERDAY 6626.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6626' 6166.81' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 12.25" STC MDSi616 JE0684 6X13 4734 6626 1892 26:20 1-1-BT-A-X-I-CT 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 6626' MW 9.3 VIS 45 PV 14 YP 20 FL 4.0 Gels 8/10/12 CL- 19000 FC 1/- SOL 5.0 SD 0.25 OIL 1.5/92.0 MBL 8.5 pH 8.5 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH- ETHANE(C-2) @ @ AVG- PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG- PENTANE(C-5) @ @ HYDROCARBON SHOWS NO FLUID CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 6626'=50%TUFFACEOUS CLAYSTONE,40%TUFFACEOUS SILTSTONE,10%CARBON SHALE AND COAL DAILY ACTIVITY WAIT ON WEATHER(HIGH WINDS),TRIP OUT OF THE HOLE FROM 1416'AND STAND BACK THE hwdp,LAY DOWN THE BHA AND REMOVE THE MWD SOURCE,LAY DOWN 3RD SUMMARY PARTY TOOLS AND CLEAN THE RIG FLOOR,MAKE UP WEAR RING,LATCH ONTIO THE WEAR RING AND WORK FREE,FUNCTION TEST THE RAMS,RIG UP TO RUN 9 5/8" CASING,BEGIN TO RUN 9 5/8"CASING EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$4145 DML,$1955 RW REPORT BY LEES F.BROWNE JR. fila•//r•\Tlrsn»manto onrl Qatfinnc\Rnt-snh Arlmin\A/TV Thnnmanto\1\/kr AX/c.1 1 0\Chc.crrrsrAltlini 1 1/1 2P)(11(1 Daily Report Page 1 of 1 CHEVRON fpQCJ-J DAILY WELLSITE REPORT M-1 1 REPORT FOR LOFT/LESLIE DATE Nov 19,2010 DEPTH 6626.00000 PRESENT OPERATION CEMENTI8NG 9 5/8"CSG TIME 24 HOURS YESTERDAY 6626.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 13.375"@ 1432' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6626' 6166.81' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SM 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 6626' MW 9.2 VIS 47 PV 16 YP 20 FL 4.4 Gels 9/12/14 CL- 19000 FC 2/- SOL 3.4 SD 0.25 OIL 1.0/94.0 MBL 10.0 pH 7.5 Ca+ 1920 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 38 @ 6626' 1 @ CIRC 7 CIRC TRIP GAS 38 @ 6626' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH- ETHANE(C-2) @ @ AVG- PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG- PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100%CEMENT DAILY ACTIVITY RUN 9 5/8"CASING TO 1428',CIRCULATE AND CONDITION THE MUD,MAXIMUM GAS WAS 1 UNIT,RUN CASING TO 6234',WASH THROUGH TIGHT SPOT AT 6234',WASH SUMMARY DOWN TO 6618',CIRCULATE AND CONDITION THE MUD,TRIP GAS WAS 38 UNITS,PREPARE TO PUMP CEMENT AT MIDNIGHT EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$4145 DML,$1995 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON H EPOCH DAILY WELLSITE REPORT M-1 1 REPORT FOR LOFT/LESLIE DATE Nov 20,2010 DEPTH 6626.00000 PRESENT OPERATION PREP TO TEST BOPE TIME 24 HOURS YESTERDAY 6626.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6626' 6166.81' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SM 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 6626' MW 9.3 VIS 46 PV 16 YP 17 FL 5.2 Gels 10/12/13 CL- 19000 FC 2/- SOL 3.4 SD 0.25 OIL 1.0/94.0 MBL 10.0 pH 7.5 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS NO DRILLING MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100%CEMENT DAILY ACTIVITY CEMENT 9 5/8"CASING TO THE HOLE,RIG DOWN CEMENTING EQUIPMENT AND MOVE TOOLS OFF THE RIG FLOOR,PREP TO TEST BOPE,FUNCTION TEST RAMS,MAKE SUMMARY UP THE TEST PLUG AND TEST JOINT,CHANGE OUT THE RAMS AND FILL THE STACK AND CHOKE WITH FLUID EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$4145 DML,$1995 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON EPOCH DAILY WELLSITE REPORT Ell M-11 REPORT FOR LOFT/LESLIE DATE Nov 21,2010 DEPTH 6626.00000 PRESENT OPERATION TRIP IN TO DRILL CEMENT TIME 24 HOURS YESTERDAY 6626.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 6626' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6626' 6166' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" STC MSi616 JE0683 3X11,3X12 6626' 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 6626' MW 9.2+ VIS 45 PV 12 YP18 FL 7.0 Gels 9/4- CL- 18500 FC 2/- SOL 5.0 SD 0.25 OIL 1.5/92.0 MBL 7.5 pH 10.5 Ca+ 2800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 1 @ TIH 0 @ TIH 0 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH- ETHANE(C-2) @ @ AVG- PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100%CEMENT DAILY ACTIVITY TEST BOPE,LAY DOWN TEST TOOLS AND CLEAN FLOOR,LOAD BIT AND STABS TO DRILL FLOOR,PICK UP BHA#5 AND RUN IN THE HOLE,TEST MWD AT 917'AT 4 G/M, SUMMARY MAXIMUM GAS WAS 1 UNIT,CUT AND SLIP NEW DRILLING LINE,SERVICE THE RIG,TRIP IN THE HOLE FROM 927 TO 2634',FILL THE DRILL PIPE,TRIP IN THE HOLEFROM 2634' TO 4151'. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4425 DML,$1955 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON L EPOCH DAILY WELLSITE REPORT M-1 1 REPORT FOR LOFT/LESLIE DATE Nov 22,2010 DEPTH 7082.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 6626.00000 24 HOUR FOOTAGE 456 CASING INFORMATION 9 5/8"@ 6626' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6626' 6166' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5"+9" STC MSi616 JE0683 3X11,3X12 6626' 23 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 164.9 @ 6723.00000 11.1 @ 6627.00000 83.2 68.64203 FT/HR SURFACE TORQUE 25498 @ 6849.00000 16629 @ 6830.00000 21127.5 0.00000 AMPS WEIGHT ON BIT 75 @ 7082.00000 0 @ 6705.00000 6.2 75.83006 KLBS ROTARY RPM 144 @ 6894.00000 0 @ 6802.00000 112.0 0.04954 RPM PUMP PRESSURE 2180 @ 7070.00000 3 @ 6802.00000 1946.4 5.63223 PSI DRILLING MUD REPORT DEPTH 6626' MW 9.2+ VIS 44 PV 12 YP 18 FL 6.0 Gels 9/12/13 CL- 19000 FC 2/- SOL 5.0 SD 0.25 OIL 1.5/92.0 MBL 10.0 pH 8.5 Ca+ 2480 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 124 @ 6868.00000 0 @ 6725.00000 14.3 TRIP GAS 18 @ 6626' CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 25595 @ 6627.00000 93 @ 6725.00000 2961.8 CONNECTION GAS HIGH 6 ETHANE(C-2) 279 @ 6796.00000 0 @ 7070.00000 14.7 AVG 2 PROPANE(C-3) 36 @ 6867.00000 0 @ 6899.00000 0.8 CURRENT 2 BUTANE(C-4) 0 @ 7082.00000 0 @ 7082.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE(C-5) 0 @ 7082.00000 0 @ 7082.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND,SANDSTONE,CONGLOMERATE SAND,CONGLOMERATE SANDSTONE,TUFFACEOUS SILT,TUFFACEOUS CLAY,COAL,CARBONACEOUS SHALE PRESENT LITHOLOGY 7080'=80%SAND,20%CONGLOMERATE SAND DAILY TRIP IN THE HOLE FROM 2634-4340'AND FILL THE DRILL PIPE,RUN IN THE HOLE TO THE STAGE COLLAR @ 4366',DRILL STAGE COLLAR 4366-4368',TRIP IN THE HOLE TO 6480' ACTIVITY AND FILL THE DRILL PIPE,TRIP IN THE HOLE TO THE FLOAT COLLAR @ 6529',CIRCULATE AND CONDITION THE HOLE,TEST THE CASING TO 3000 PSI,DRILL THE FLOAT COLLAR SUMMARY 6529-6533',DRILL CEMENT COLLAR 6533-6612',CIRCULATE AND CONDITION THE HOLE,RIG SAFETY DRILLS,DRILL CEMENT TO 6618',CIRCULATE AND CONDITION THE HOLE, TRIP GAS WAS 18 UNITS,DRILL TO 6646'AND RUN A FIT TO 13.0 EMW,DRILL FORMATION PUMPING HIGH VISCOSITY SWEEPS EVERY CONNECTION. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4425 DML,$1955 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT PI EPOCH M-11 REPORT FOR LOFT/LESLIE DATE Nov 23,2010 DEPTH 8005.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 7082.00000 24 HOUR FOOTAGE 923' CASING INFORMATION 9 5/8"@ 6626' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7700 43.89 25.16 7071.16 SURVEY DATA 7215.09 39.90 29.88 6713.07 7025.40 37.12 37.11 6565.59 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5"+9" STC MSi616 JE0683 3X11,3X12 6626' 25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 133.8 @ 7237.00000 4.3 @ 7884.00000 61.2 10.88200 FT/HR SURFACE TORQUE 25190 @ 7531.00000 19358 @ 7731.00000 22363.1 22132.33200 AMPS WEIGHT ON BIT 11 @ 7982.00000 0 @ 7475.00000 6.6 10.21100 KLBS ROTARY RPM 145 @ 7118.00000 75 @ 7973.00000 116.9 80.93100 RPM PUMP PRESSURE 2251 @ 7845.00000 1698 @ 7220.00000 2132.8 2185.05600 PSI DRILLING MUD REPORT DEPTH 7905' MW 9.2+ VIS 47 PV 18 VP 21 FL 4.4 Gels 8/12/13 CL- 19000 FC 2/- SOL 5.6 SD 0.30 OIL 2.5/90.4 MBL 8.8 pH 8.5 Ca+ 2240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 215 @ 7580.00000 1 @ 7945.00000 28.7 TRIP GAS- CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 37650 @ 7555.00000 172 @ 7967.00000 4580.5 CONNECTION GAS HIGH 10 @ 7463' ETHANE(C-2) 385 @ 7555.00000 0 @ 7406.00000 41.4 AVG 3 PROPANE(C-3) 112 @ 7569.00000 0 @ 7834.00000 7.9 CURRENT 6 BUTANE(C-4) 67 @ 7545.00000 0 @ 7644.00000 1.6 CURRENT BACKGROUND/AVG 7 PENTANE(C-5) 0 @ 8005.00000 0 @ 8005.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE,TUFFACEOUS CLAY,SAND,SANDSTONE,CONGLOMERATE,CONGLOMERATE SAND PRESENT LITHOLOGY 8000'=50%TUFFACEOUS SILTSTONE,50%TUFFACEOUS CLAY DAILY ACTIVITY SUMMARY DRILL FORMATION TO 8005',PUMPING HIGH VISCOSITY SWEEPS AT EVERY OTHER CONNECTION OR WHEN NEEDED EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4425 DML,$1955 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT HI EPOCH M-11 REPORT FOR MENAPACE/LESLIE DATE Nov 24,2010 DEPTH 8039.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 8005.00000 24 HOUR FOOTAGE 34' CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7972.61 43.69 23.07 7268.11 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5"+9" STC MSi616 JE0683 3X11,3X12 6626' 8034' 1407' 27:42 0-3-WT-T-X-O-CT PR 5 8.5"-I-9" STC MSi616 JE0685 3X11,3X12 8034' .5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 36.8 @ 8036.00000 3.9 @ 8019.00000 15.6 25.94445 FT/HR SURFACE TORQUE 23416 @ 8037.00000 21061 @ 8009.00000 22941.3 23083.33398 AMPS WEIGHT ON BIT 12 @ 8033.00000 0 @ 8036.00000 8.7 0.85316 KLBS ROTARY RPM 98 @ 8018.00000 78 @ 8030.00000 83.6 81.21724 RPM PUMP PRESSURE 2203 @ 8026.00000 2012 @ 8037.00000 2238.7 2132.56421 PSI DRILLING MUD REPORT DEPTH 8034' MW 9.2 VIS 47 PV 14 YP 21 FL 4.4 Gels 7/9/10 CL- 20000 FC 1/- SOL 4.6 SD 0.25 OIL -/93.7 MBL 7.5 pH 9.5 Ca-i- 2080 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 46 @ 8039.00000 4 @ 8007.00000 10.0 TRIP GAS 202 @ 8034' CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 8816 @ 8039.00000 678 @ 8007.00000 13003 CONNECTION GAS HIGH - ETHANE(C-2) 71 @ 8039.00000 2 @ 8034.00000 3.5 AVG- PROPANE(C-3) 13 @ 8039.00000 0 @ 8034.00000 0.6 CURRENT- BUTANE(C-4) 0 @ 8039.00000 0 @ 8039.00000 0.0 CURRENT BACKGROUND/AVG 8 PENTANE(C-5) 0 @ 8039.00000 0 @ 8039.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL,CARBONACEOUS SHALE AND CLAY,TUFFACEOUS SILT AND CLAY PRESENT LITHOLOGY 8039'=50%COAL,50%CARBONACEOUS SHALE DRILL FORMATION TO 8034',CIRCULATE AND CONDITION THE HOLE,TRIP OUT OF THE HOLE TO 6610',CIRCULATE AND CONDITION THE HOLE AND MONITOR THE WELL,TRIP DAILY OUT OF THE HOLE TO 832',LAY DOWN THE BIT AND THE MWD TOOLS AND SECURE THE SOURCE,LAY DOWN THE REST OF THE BHA,SERVICE THE TOP DRIVE,MAKE UP THE ACTIVITY NEW BIT,BHA AND MWD TOOLS AND RUN IN THE HOLE TO 3620',CIRCULATE AND CONDITION THE HOLE WITH SIX UNITS MAXIMUM GAS,TRIP IN THE HOLE TO 6780', SUMMARY CIRCULATE AND CONDITION THE HOLE,MAXIMUM GAS WAS ONE UNIT,TRIP IN THE HOLE TO 7945'WASH AND REAM TO BOTTOM 8034'TRIP GAS WAS 202 UNITS,DRILL FORMATION TO 8039' EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4125 DML,$1955 RW REPORT BY LEES F.BROWNE JR file://C7\nnenments and Settings\RnochAdmin\Mv Documents\Mv Wells\Chevron\20101-.. 11/24/2010 Daily Report Page 1 of 1 CHEVRON PI EPOCH DAILY WELLSITE REPORT M-1 1 REPORT FOR MENAPACE/LESLIE DATE Nov 25,2010 DEPTH 8686.00000 PRESENT OPERATION TRIP OUT FOR DRILL PIPE WASH OUT TIME 24 HOURS YESTERDAY 8039.00000 24 HOUR FOOTAGE 647' CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8447.78 43.42 26.37 7612.68 SURVEY DATA 8352.97 43.51 26.38 7543.87 8258.24 43.57 25.14 7475.20 8163.37 43.42 25.41 7406.38 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5"+9" STC MSi616 JE0685 3X11,3X12 6034' 17 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 80.2 @ 8256.00000 5.6 @ 8049.00000 44.9 44.41400 FT/HR SURFACE TORQUE 26211 @ 8395.00000 22849 15' 8170.00000 24876.0 2512024400 AMPS WEIGHT ON BIT 11 @ 8223.00000 0 @ 8417.00000 4.9 8.07300 KLBS ROTARY RPM 128 @ 8648.00000 14 @ 8048.00000 116.6 125.68900 RPM PUMP PRESSURE 2292 @ 8627.00000 1674 @ 8319.00000 2220.9 2252.62700 PSI DRILLING MUD REPORT DEPTH 8034' MW 9.2 VIS 47 PV 14 YP 21 FL 4.4 Gels 7/9/10 CL- 20000 FC 1/- SOL 4,6 SD 0.25 OIL -/93.7 MBL 7.5 pH 9.5 Ca+ 2080 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 189 @ 8528.00000 0 @ 8095.00000 34.3 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) 34528 @ 8277.00000 61 @ 8095.00000 5403.6 CONNECTION GAS HIGH 4 ETHANE(C-2) 474 @ 8276.00000 0 @ 8069.00000 49.4 AVG 4 PROPANE(C-3) 235 @ 8525.00000 0 @ 8069.00000 10.8 CURRENT 4 BUTANE(C-4) 91 @ 8427.00000 1 @ 8469.00000 2.4 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 0 @ 8686.00000 0 @ 8686.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CONGLOMERATE SAND,SAND,CONGLOMERATE,TUFFACEOUS SILT,TUFFACEOUS CLAY,COAL,CARBON SHALE PRESENT LITHOLOGY 8680'=90%TUFFACEOUS SILTSTONE,10%SAND DAILY ACTIVITY DRILL FORMATION TO 8686',TRIP OUT OF THE HOLE LOOKING FOR DRILL PIPE WASH OUT,PULL OUT TO 6763'AND LAY DOWN THE BAD JOINT,PICK UP NEW JOINT AND SUMMARY TRIP OUT OF THE HOLE TO THE SHOE(6617)AND MONMITOR THE HOLE,SERVICE THE TOP DRIVE. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4125 DML,$1955 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON 11 1EPIII}HII DAILY WELLSITE REPORT M-1 1 REPORT FOR MENAPACE/LESLIE DATE Nov26,2010 DEPTH 9209.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 8686.00000 24 HOUR FOOTAGE 523' CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8922.10 43.34 27.18 7957.13 SURVEY DATA 8732.99 43.43 26.60 7819.24 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5"+9" STC MSi616 JE0685 3X11,3X12 8034' 30 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 79.1 @ 8919.00000 6.0 @ 8933.00000 44.0 24.91281 FT/HR SURFACE TORQUE 27146 @ 9083.00000 23804 @ 8932.00000 25937.2 26044.92188 AMPS WEIGHT ON BIT 9 @ 8752.00000 0 @ 9208.00000 4.8 0.31192 KLBS ROTARY RPM 145 @ 9174.00000 0 @ 9077.00000 133.5 142.86327 RPM PUMP PRESSURE 2363 @ 9206.00000 3 @ 9077.00000 2275.4 2340.14697 PSI DRILLING MUD REPORT DEPTH 8686' MW 9.2+ VIS 44 PV 13 YP 18 FL 5.0 Gels 7/9/10 CL- 20000 FC 1/- SOL 4.9 SD 0.30 OIL -/93.5 MBL 8.5 pH 8.8 Ca+ 1800 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 220 @ 8921.00000 2 @ 9156.00000 47.5 TRIP GAS- CUTTING GAS @ @ WIPER GAS 248 @ 8686' CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 49084 @ 8921.00000 406 @ 9156.00000 9491.1 CONNECTION GAS HIGH 6 ETHANE(C-2) 237 @ 8921.00000 0 @ 9114.00000 56.7 AVG 3 PROPANE(C-3) 55 @ 9177.00000 0 @ 9114.00000 9.0 CURRENT 4 BUTANE(C-4) 13 @ 8831.00000 0 @ 8878.00000 0.5 CURRENT BACKGROUND/AVG 21 PENTANE(C-5) 0 @ 9209.00000 0 @ 9209.00000 0.0 HYDROCARBON GAS SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9042 TO 9070' SAND 80-100% BEFORE 20 MAX 118 SAND VLTGY,MEDIUM LOWER TO FINE LOWER,ARENACEOUS UNCONSOLIDATED,GRAIN SUPPORTED,GODS POROSITY AFTER 40 AND PERMEABILITY,NO SHOW OF OIL INDICATORS. LITHOLOGY SAND,SANDSTONE,CONGLOMERATE SAND,COAL,CARBON SHALE,TUFFACEOUS SILT,TUFFACEOUS CLAY PRESENT LITHOLOGY 9210'=SAND 60%,SANDSTONE 10%,CONGLOMERATE SAND 10%,TUFFACEOUS SILTSTONE 10%,TUFFACEOUS CLAY 10 DAILY ACTIVITY SUMMARY TRIP IN THE HOLE TO 8608',WASH AND REAM TO 8686',WIPER GAS WAS 248 UNITS,DRILL FORMATION TO 9209'AND TEST THE FORMATION. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4125 DML,$1955 RW REPORT BY LEES F.BROWNE JR. P 1 I//'1,1-. , fl .. ,1-, 1 ♦ 1 • 11.r 1', ,1.I" «7 11 ,/-11 1.1.r 1 1 ,/1.11","1,. Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT PI EPOCH .11 REPORT FOR MENAPACE/LESLIE DATE Nov27,2010 DEPTH 9399.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 9209.00000 24 HOUR FOOTAGE 190' CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9206.61 43.86 26.07 8163.55 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5"+9" STC MSi616 JE0685 3X11,3X12 8034' 36 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 89.8 @ 9288.00000 12.0 @ 9290.00000 41.5 62.93156 FT/HR SURFACE TORQUE 27095 @ 9255.00000 19823 @ 9293.00000 23414.4 23958.87891 AMPS WEIGHT ON BIT 12 @ 9291.000000 @ 9252.00000 4.1 6.80775 KLBS ROTARY RPM 151 @ 9259.00000 0 @ 9364.00000 132.4 100.96042 RPM PUMP PRESSURE 2490 @ 9353.00000 1904 @ 9370.00000 2388.9 2438.85913 PSI DRILLING MUD REPORT DEPTH 9202' MW 9.2+ VIS 44 PV 15 YP 20 FL 4.6 Gels 8/10/11 CL- 20000 FC 1/- SOL 4.9 SD 0.30 OIL -/93.5 MBL 8.5 pH 8.5 Ca+ 1760 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 49 @ 9380.00000 4 @ 9362.00000 15.0 TRIP GAS- CUTTING GAS 0 @ 9399.00000 0 @ 9399.00000 0.0 WIPER GAS 136 @ 9268' CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 8288 @ 9331.00000 431 @ 9390.00000 22032 CONNECTION GAS HIGH 0 ETHANE(C-2) 337 @ 9380.00000 0 @ 9265.00000 39.4 AVG 0 PROPANE(C-3) 110 @ 9331.00000 0 @ 9235.00000 3.3 CURRENT 0 BUTANE(C-4) 0 @ 9399.00000 0 @ 9399.00000 0.0 CURRENT BACKGROUND/AVG 15 PENTANE(C-5) 0 @ 9399.00000 0 @ 9399.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILT,TUFFACEOUS CLAY,SAND,SANDSTONE,CONGLOMERATE SAND CONCLOMERATE,COAL,CARBON SHALE PRESENT LITHOLOGY 9390'=90%TUFFACEOUS SILT,10%CARBONACEOUS SHALE/CLAY DAILY ACTIVITY DRILL FORMATION TO 9267',WORK DRILL PIPE,HOLE TIGHT HIGH TORQUE,WORK DRILL PIPE FROM 9177-9267',TRIP OUT OF THE HOLE TO 6522',CLEAN THE RIG FLOOR, SUMMARY PICK UP STAGE TOOLS,SERVICE THE RIG,INSTALL TORQUE REDUCERS ON THE DRILL PIPE TRIPPING IN THE HOLE,WIPER GAS WAS 136 UNITS,DRILL FORMATION EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4125 DML,$1955 RW REPORT BY LEES F.BROWNE JR. Daily Report Page 1 of 1 CHEVRON PI EPOCH DAILY WELLSITE REPORT M-1 1 REPORT FOR MENAPACE/LESLIE DATE Nov 28,2010 DEPTH 10146.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 9399.00000 24 HOUR FOOTAGE 747' CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9775.50 43.88 23.2 8573.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB/C PULLED 5 8.5"+9" STC MSi616 JE0685 3X11,3X12 8034' 33 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 84.0 @ 9952.00000 7.9 @ 10140.00000 47.3 50.63932 FT/HR SURFACE TORQUE 26256 @ 9865.00000 18173 @ 10059.00000 22570.8 21252.05664 AMPS WEIGHT ON BIT 13 @ 10142.00000 0 @ 9647.00000 8.7 11.78457 KLBS ROTARY RPM 182 @ 9583.00000 0 @ 10121.00000 122.1 129.60812 RPM PUMP PRESSURE 2596 @ 10060.00000 2021 @ 9841.00000 2464.9 2524.79858 PSI DRILLING MUD REPORT DEPTH 9331' MW 9.2+ VIS 45 PV 15 YP 19 FL 4.7 Gels 6/7/8 CL- 22000 FC 1/- SOL 4.8 SD 0.50 OIL -/93.4 M8L 8.0 pH 9.2 Ca+ 1120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 238 @ 9958.00000 3 @ 9538.00000 46.9 TRIP GAS- CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 32058 @ 9933.00000 592 @ 9494.00000 7397.5 CONNECTION GAS HIGH 0 ETHANE(C-2) 1577 @ 9957.00000 0 @ 9541.00000 159.5 AVG 0 PROPANE(C-3) 1255 @ 9957.00000 0 @ 9459.00000 89.1 CURRENT 0 BUTANE(C-4) 808 @ 9957.00000 2 @ 9988.00000 48.8 CURRENT BACKGROUND/AVG 22 PENTANE(C-5) 176 @ 10015.00000 0 @ 9988.00000 7.4 HYDROCARBON OIL SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9940 TO 9967' 90%SAND 10% BEFORE 70 MAX 238 UNCONSLOIDATED SAND,MED-F GR,GRAIN SUPPORTED,>80%MOD YELGRN EVN OIL FLOR,SPOTTY FAINT LT BRN OIL SANDSTONE AFTER 25 STN,WK SLO STRMG OIL CUT SLOW INCR TO MOD MILKY CUT,FAIR OIL SHOW LITHOLOGY SAND,SANDSTONE,CONGLOMERATE SAND,TUFFACEOUS SILT,TUFFACEOUS CLAY,COAL,CARBON SHALE PRESENT LITHOLOGY 10140'=70%SAND,20%CONGLOMERATE SAND,10%SANDSTONE DAILY ACTIVITY SUMMARY DRIL FORMATION WITH NO CONNECTION GASES,HIGH VISCOSITY SWEEPSBRING BACK INCREASED CUTTINGS EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4125 DML,$1955 RW REPORT BY LEES F.BROWNE JR. file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Chevron\20101... 11/28/2010 Daily Report Page 1 of 1 CHEVRON EPOCH DAILY WELLSITE REPORT 1E1 M-1 1 REPORT FOR MENAPACE/LESLIE DATE Nov 29,2010 DEPTH 10290.00000 PRESENT OPERATION TOOH FOR CSG TIME 24 HOURS YESTERDAY 10146.00000 24 HOUR FOOTAGE 144 •I CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10290 8944.97 SURVEY DATA 10224.64 43.74 24.3 8897.75 1015481 43.59 2423 8847.23 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5"+9" STC MSi616 JE0685 3X11,3X12 8034' 10290' 2256' 65:21 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 50.6 @ 10146.00000 2.5 @ 10212.00000 22.1 12.92700 FT/HR SURFACE TORQUE 26699 @ 10156.00000 17862 @ 10244.00000 21922.1 0.00000 AMPS WEIGHT ON BIT 15 @ 10245.00000 3 @ 10158.00000 10.6 13.33800 KLBS ROTARY RPM 137 @ 10151.00000 71 @ 10277.00000 118.5 0.00000 RPM PUMP PRESSURE 2557 @ 10156.00000 2407 @ 10241.00000 2477.5 0.00000 PSI DRILLING MUD REPORT DEPTH 10070' MW 9.3+ VIS 45 PV 14 YP 20 FL 5.0 Gels 5/9/10 CL- 22000 FC 1/- SOL 5.2 SD 0.50 OIL -/93.0 MBL 10.0 pH 8.9 Ca+ 1440 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 62 @ 10220.00000 9 @ 10285.00000 27.4 TRIP GAS CUTTING GAS @ @ WIPER GAS 173 @ 10290' CHROMATOGRAPHY(ppm) SURVEY 0 METHANE(C-1) 10200 @ 10221.00000 1392 @ 10285.00000 3683.1 CONNECTION GAS HIGH 1 ETHANE(C-2) 598 @ 10150.00000 41 @ 10285.00000 181.5 AVG 1 PROPANE(C-3) 437 @ 10182.00000 9 @ 10285.00000 142.8 CURRENT 0 BUTANE(C-4) 310 @ 10182.00000 4 @ 10285.00000 105.8 CURRENT BACKGROUND/AVG 0 PENTANE(C-5) 136 @ 10182.00000 4 @ 10285.00000 40.0 HYDROCARBON OIL SHOW SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10171 TO 10210' 80%SAND,20%CONGLOMERATE SAND C-1 TO C-5 BEFORE 22 MAX SAND=MED UPR TO FINE UPR,GRAIN SUPOORTED,NO STAIN,NO ODOR,80%EVEN YELLOW GRN NOTED CROSS OVER ON GAS RATIO LOG 38 AFTER 20 SMPL FLOR,INST LIBLUWHT TRANSL SL-MOD CUT,SLO DEVLP TO MOD BLU/WHT TRANSL CUT,SL YELGRN RESD STN LITHOLOGY SAND,SANDSTONE,CONGLOMERATE SAND,TUFFACEOUS SILT,COAL,CARBON SHALE PRESENT LITHOLOGY 10290'=50%COAL,20%CARBON SHALE,30%TUFFACEOUS SILTSTONE DAILY ACTIVITY DRILL FORMATION TO 10290',CIRCULATE AND CONDITION THE HOLE,PUMP SWEEP AND CIRCULATE AND CONDITION THE HOLE,WIPER TRIP TO 9085',CIRCULATE AND SUMMARY CONDITION THE WELL,TRIP IN THE HOLE AND WASH THE LAST STAND DOWN,SLIGHT PACK OFF,CIRCULATE SWEEP AND LCM PILL,WIPER GAS WAS 178 UNITS,TRIP OUT OF THE HOLE TO 832' EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW+2 SC DAILY COST$4125 DML,$1955 RW REPORT BY LEES F.BROWNE JR. f;io•iirmul,,,.,,,,,o„*e .,,,,l cob*;,,,.e\r,,,,,.ti,A,a,,,;„\r4., n,.,.,,,,,o„*AA7r„Am.iie\rn,o.,,-,.,,vvnin1 11 i')oi')ni n Daily Report Page 1 of 1 CHEVRON II EPOCH DAILY WELLSITE REPORT M-1 1 REPORT FOR MENAPACE/LESLIE DATE Nov 29,2010 DEPTH 10290.00000 PRESENT OPERATION RUN 7"LINER TIME 24 HOURS YESTERDAY 10290.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9 5/8"@ 6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10290 8944.97 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5"a9" STC MSi616 JE0635 3X11,3X12 8034' 10290' 2256' 65:21 2-4-WT-N-X-I-CT 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 10290' MW 9.3 VIS 41 PV 13 YP 16 FL 5.0 Gels 4/6/7 CL- 21000 FC 1/- SOL 5.3 SD 0.50 OIL -/93.0 MBL 7.5 pH 8.6 Ca+ 1280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE(C-1) @ @ CONNECTION GAS HIGH ETHANE(C-2) @ @ AVG PROPANE(C-3) @ @ CURRENT BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG PENTANE(C-5) @ @ HYDROCARBON SHOWS NO MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10290'=50%COAL,20%CARBON SHALE,30%TUFFACEOUS SILTSTONE DAILY ACTIVITY STAND BACK THE FIWDP,LAY DOWN THE BHA,SOURCE AND TOOLS,CLEAN THE RIG FLOOR,SERVICE THE RIG,RIG UP TO RUN 7"CASING,MAKE UP THE SHOE TRACK SUMMARY AND TESTFLOATS,WAIT ON HIGH WINDS,BEGIN TO RUN 7"CASING FROM 1080'TO 1390' EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$3325 DML,$1955 RW REPORT BY LEES F.BROWNE JR. file://C:\Documents and Settings\EpochAdmin\My Documents\My Wells\Chevron\Morni... 11/30/2010 Daily Report Page 1 of 1 CHEVRON DAILY WELLSITE REPORT EPOCH .11 REPORT FOR MENAPACE/HAUCK DATE Dec 01,2010 DEPTH 10290.00000 PRESENT OPERATION ON BOTTOM WITH LINER CIRC. TIME 24 HOURS YESTERDAY 10290.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9 5/8"@6615' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10290 8944.97 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N 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 10290' MW 9.3 VIS 41 PV 13 VP 16 FL 5.0 Gels 4.6/7 CL- 21000 FC 1/- SOL 5.3 SD 0.50 OIL -/93.0 MBL 7.5 pH 8.6 Ca+ 1280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 78 @ TG 4 @ TIH 12 TRIP GAS 78 @ 10290' CUTTING GAS @ @ WIPER GAS- CHROMATOGRAPHY(ppm) SURVEY- METHANE(C-1) @ @ CONNECTION GAS HIGH- ETHANE(C-2) @ @ AVG- PROPANE(C-3) @ @ CURRENT- BUTANE(C-4) @ @ CURRENT BACKGROUND/AVG 22 PENTANE(C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10290'=50%COAL,20%CARBON SHALE,30%TUFFACEOUS SILTSTONE RUN PIPE FROM 1310'TO N1921',LAY DOWN BAD JOINT,RUN IN THE HOLE TO 3860',MAKE UP HANGER ASSEMBLY,RUN IN THE HOLE TO 4081',TRIP IN THE HOLE WITH 7" DAILY ACTIVITY DAILYLINER ON 5"DRILL PIPE TO 6600',INSTALL CEMENT LINES AND MAKE UP THE CEMENT HEAD,TRIP IN THE HOLE WITH THE LINER BON 5"DRILL PIPE TO 9900',TAG UP AND SUMMARY WASH THROUGH AND RUN IN THE HOLE TO 12080',CIRCULATE AND CONDITION,TRIP GAS WAS 84 UNITS,HOLE TORQUE AND HOLE PACKING OFF SLIGHTLY,CONTINUE TO CIRCULATE AND CONDITION THE HOLE. EPOCH PERSONNEL ON BOARD BROWNE,WINSLOW DAILY COST$3325 DML,$1955 RW REPORT BY LEES F.BROWNE JR. fila•//f•\Tlnniimantc anr1 Cattinac\FnnrhArlmin\Mx/ Tlnrnmantc\Mx/WP11c\Ch'. , nn\' flini7 1//i/'111A -n 0 0 z r 0 CA OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format.
