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Home My WebLink About212-041Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250919 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-35T 50283200970000 198161 8/10/2025 AK E-LINE PPROF T40899 BRU 223-34T 50283202060000 225059 8/17/2025 AK E-LINE CBL T40900 BRU 234-27 50283202070000 225065 9/12/2025 AK E-LINE CBL T40901 BRU 242-04 50283201640000 212041 6/9/2025 AK E-LINE Perf T40902 KBU 11-08Z 50133206290000 214044 9/8/2025 AK E-LINE Perf T40903 MPU H-03 50029220630000 190088 9/9/2025 AK E-LINE SetPacker T40904 MPU H-11 50029228020000 197163 2/9/2025 AK E-LINE Caliper T40905 MPU M-62 50029237440000 223006 8/31/2025 AK E-LINE LDL T40906 NCIU A-06 50883200260000 169050 8/25/2025 AK E-LINE TubingCut T40907 NCIU A-21A 50883201990100 225075 8/26/2025 AK E-LINE Perf T40908 ODSK-33 50703205620000 207183 9/10/2025 READ Caliper Survey T40909 ODSN-01a 50703206480100 216008 9/8/2025 READ Caliper Survey T40910 ODSN-06 50703207150000 215098 9/9/2025 READ Jewelry Log T40911 PBU C-34C 50029217850300 225068 8/25/2025 BAKER MRPM T40912 PBU Q-06A 50029203460100 198090 8/21/2025 BAKER SPN T40913 TBU M-25 50733203910000 187086 8/31/2025 AK E-LINE Drift T40914 Please include current contact information if different from above. BRU 242-04 50283201640000 212041 6/9/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.22 13:22:50 -08'00' 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): 7,221'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 518' MD/TVD; chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: September 10, 2025 See Schematic See Schematic 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 Chad Helgeson, Operations Engineer Camco TMAXX-53 SSSV; AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029656 212-041 50-283-20164-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 3,317' MDLength 9.3# / L-80 TVD Burst 3,627' 7,240psi 2,831' See Attached Schematic 5,750psi 110'110' 3,335' 87' 7,210' Perforation Depth MD (ft): 7,192' Beluga River Unit (BRU) 242-04CO 802A Same 6,640'7" ~1602 psi See Schematic 9-5/8" Size Will perfs require a spacing exception due to property boundaries? See Attached Schematic 6,650'5,400'4,856' Beluga River Sterling-Beluga Gas 20" 3-1/2" m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov DOA: Noel Nocas Out of Office By Grace Christianson at 3:46 pm, Aug 26, 2025 Digitally signed by Ryan Lemay (14113) DN: cn=Ryan Lemay (14113) Date: 2025.08.26 15:28:33 - 08'00' Ryan Lemay (14113) 325-519 A.Dewhurst 28AUG25 DSR-8/26/25BJM 9/2/25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.03 08:27:54 -08'00' 09/03/25 RBDMS JSB 090425 Well Prognosis Well Name: BRU 242-04 API Number: 50-283-20164-00-00 Current Status: Gas Producer Permit to Drill Number: 212-041 First Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (M) Maximum Expected BHP: ~1734 psi @ 3770’ TVD (Based on 0.46 psi/ft gradient new sand) Max. Potential Surface Pressure: ~1602 psi (Based on 0.035 psi/ft gas gradient to surface) Applicable Frac Gradient: .82 psi/ft using 15.7 ppg EMW FIT at the surface casing 6/12/12 Shallowest Allowable Perf TVD: MPSP/(0.82-0.035) = 1602 psi / 0.785 = 2040’ TVD Top of Pool per CO 802A: 3429’ MD & 2918’ TVD Well Status: Gas producer making ~550 mcfd, ~80 bwpd @ 50-100psi, dropping 1 soap stick every 60 minutes. Currently has an open AOGCC sundry (# 325-471) to install a capillary string in the well. Brief Well Summary: BRU 242-04 was drilled and completed in 2012 as a Beluga G, H, I sands. It was subsequently fracture stimulated after the rig was moved off, but was shut in as a result of water production with little to no gas. It was then worked over in 2014 and the previous zones were isolated and the Sterling A thru the Beluga F sand were added, gravel packed and isolated with a packer & sleeves with a Superior completion system. Sterling A was opened in Jun 2018 and added 1.3 mmscfd and slowly declined. In November 2022 the well loaded with water. In October 2023 perforations were added through the gravel pack and rate increased until water loaded up in January 2024. In 2024 additional perforations were added through the gravel pack of sands that were not initially perforated during the gravel pack. Well is currently swinging ~75 psi on every soap drop and have to hold back pressure for sand production due to the swings on the well. The purpose of this work/sundry is perforate a zone that has been bypassed prior to installing the capillary string. Notes Regarding Wellbore Condition x 3.5” gravel pack completion x Well flows 80 bwpd x Inclination o Max deviation of 52° @ 1936’ MD Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 2,500 psi high 3. RIH and perforate per RE/Geo the following sand: Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Sands Top MD Btm MD Top TVD Btm TVD Amt BEL D3 ±4,285' ±4,298' ±3,758' ±3,770' ±13' _____________________________________________________________________________________ Pg.1 Updated by CAH 06-23-25 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’ 6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry #Depth MD (ft.)ID (in.)Description 1 18’3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518’2.812 Camco TMAXX-5E SCSSV X Profile SN C-135-0852 3 3460’2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519’2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576’2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING/TUBING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''5130’' JEWELRY DETAIL –See Superior Schematic for more details *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are Gravel pack sleeves, not shiftable by slickline #Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Gravel pack Sleeve & circ valve 3778 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Superior Isolation Packer 7027 NI B5 3824 2.75 Gravel Pack Sleeve & circ valve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Superior Isolation Packer 7027 NI C5 3954 2.75 Gravel Pack Sleeve & circ valve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Superior Isolation Packer 7027 NI E5 4222 2.75 Gravel Pack Sleeve & circ valve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Gravel Pack Sleeve & circ valve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ _____________________________________________________________________________________ Pg.2 Updated by CAH 06-23-25 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 13' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 7/20/2012 Grvl Pck Beluga D1 4,237’ 4,241’ 3,710’ 3,714’ 4’ 3/13/24 Open Beluga D2 4,257’ 4,259’ 3,730’ 3,732’’ 2’ 3/13/24 Open Beluga D4 4,319’ 4,323’ 3,791’ 3,795’ 4’ 3/13/24 Open Beluga D6 4,378’ 4,382’ 3,849’ 3,853’ 4’ 3/13/24 Open Beluga D7 4,405’ 4,412’ 3,876’ 3,883’ 7’ 3/12/24 Open Beluga E1 4,453’ 4,466’ 3,923’ 3,936’ 13’ 3/12/24 Open Beluga E1 4,480’ 4,500’ 3,950’ 3,970’ 20’ 3/12/24 Open Beluga E 4,500' 4,514' 3,969' 3,983' 14' 7/20/2012 Grvl Pck Beluga E4 4,629’ 4,638’ 4,096’ 4,105’ 9’ 3/12/24 Open Beluga E5 4,645’ 4,652’ 4,112’ 4,119’ 7’ 3/12/24 Open Beluga E5 4,685’ 4,695’ 4,151’ 4,161’ 10’ 3/12/24 Open Beluga E 4,704' 4,714' 4,170' 4,180' 10' 7/20/2012 Grvl Pck Beluga E5 4,717’ 4,724’ 4,183’ 4,190’ 7’ 3/12/24 Open E6 4,745’ 4,754’ 4,210’ 4,219’ 9' 10/8/2023 Open E6 4,764’ 4,770’ 4,229’ 4,235’ 6' 10/8/2023 Open Beluga E6 4,777’ 4,784’ 4,242’ 4,249’ 7’ 3/12/24 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 9' 10/8/2023 Open Beluga F 4,970' 4,982' 4,432' 4,444' 12' 7/20/2012 Grvl Pck F6 5,018’ 5,023’ 4,479’ 4,484’ 5' 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 8' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 13' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 5' 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 4' 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 5' 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 14' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 16' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 16' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 20' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 5' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 11' 7/20/2012 Plugged _____________________________________________________________________________________ Pg.1 Updated by CAH 08-26-25 PROPOSED Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’ 6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry #Depth MD (ft.)ID (in.)Description 1 18’3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518’2.812 Camco TMAXX-5E SCSSV X Profile SN C-135-0852 3 3460’2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519’2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576’2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING/TUBING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''5130’' JEWELRY DETAIL –See Superior Schematic for more details *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are Gravel pack sleeves, not shiftable by slickline #Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Gravel pack Sleeve & circ valve 3778 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Superior Isolation Packer 7027 NI B5 3824 2.75 Gravel Pack Sleeve & circ valve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Superior Isolation Packer 7027 NI C5 3954 2.75 Gravel Pack Sleeve & circ valve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Superior Isolation Packer 7027 NI E5 4222 2.75 Gravel Pack Sleeve & circ valve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Gravel Pack Sleeve & circ valve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ _____________________________________________________________________________________ Pg.2 Updated by CAH 08-26-25 PROPOSED Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 13' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 7/20/2012 Grvl Pck Beluga D1 4,237’ 4,241’ 3,710’ 3,714’ 4’ 3/13/24 Open Beluga D2 4,257’ 4,259’ 3,730’ 3,732’’ 2’ 3/13/24 Open Beluga D3 ±4,285’ ±4,298’ ±3,758’ ±3,770’ ±13 TBD Proposed Beluga D4 4,319’ 4,323’ 3,791’ 3,795’ 4’ 3/13/24 Open Beluga D6 4,378’ 4,382’ 3,849’ 3,853’ 4’ 3/13/24 Open Beluga D7 4,405’ 4,412’ 3,876’ 3,883’ 7’ 3/12/24 Open Beluga E1 4,453’ 4,466’ 3,923’ 3,936’ 13’ 3/12/24 Open Beluga E1 4,480’ 4,500’ 3,950’ 3,970’ 20’ 3/12/24 Open Beluga E 4,500' 4,514' 3,969' 3,983' 14' 7/20/2012 Grvl Pck Beluga E4 4,629’ 4,638’ 4,096’ 4,105’ 9’ 3/12/24 Open Beluga E5 4,645’ 4,652’ 4,112’ 4,119’ 7’ 3/12/24 Open Beluga E5 4,685’ 4,695’ 4,151’ 4,161’ 10’ 3/12/24 Open Beluga E 4,704' 4,714' 4,170' 4,180' 10' 7/20/2012 Grvl Pck Beluga E5 4,717’ 4,724’ 4,183’ 4,190’ 7’ 3/12/24 Open E6 4,745’ 4,754’ 4,210’ 4,219’ 9' 10/8/2023 Open E6 4,764’ 4,770’ 4,229’ 4,235’ 6' 10/8/2023 Open Beluga E6 4,777’ 4,784’ 4,242’ 4,249’ 7’ 3/12/24 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 9' 10/8/2023 Open Beluga F 4,970' 4,982' 4,432' 4,444' 12' 7/20/2012 Grvl Pck F6 5,018’ 5,023’ 4,479’ 4,484’ 5' 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 8' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 13' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 5' 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 4' 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 5' 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 14' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 16' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 16' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 20' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 5' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 11' 7/20/2012 Plugged 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: Install Cap String 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): 7,221'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See Attached Schematic 6,650'5,400'4,856' Beluga River Sterling-Beluga Gas 20" 3-1/2" Beluga River Unit (BRU) 242-04CO 802A Same 6,640'7" ~1139 psi See Schematic 9-5/8" Size Will perfs require a spacing exception due to property boundaries? 7,210' Perforation Depth MD (ft): 7,192' See Attached Schematic 5,750psi 110'110' 3,335' 87' 3,317' MDLength 9.3# / L-80 TVD Burst 3,627' 7,240psi 2,831' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029656 212-041 50-283-20164-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: 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 Chad Helgeson, Operations Engineer Camco TMAXX-53 SSSV;518' MD/TVD; chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: August 22, 2025 See Schematic See Schematic m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:01 pm, Aug 08, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.08 14:39:55 - 08'00' Noel Nocas (4361) 325-471 A.Dewhurst 13AUG25 DSR-8/14/25 10-404 BJM 8/18/25JLC 8/18/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.19 06:58:38 -08'00'08/19/25 RBDMS JSB 082025 Well Prognosis Well Name: BRU 242-04 API Number: 50-283-20164-00-00 Current Status: Gas Producer Permit to Drill Number: 212-041 First Call Engineer: Chad Helgeson (907) 777-8420 (O) (907) 229-4824 (M) Second Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (M) Maximum Expected BHP: ~1305 psi @ 4734’ TVD (Based on 2023 Survey) Max. Potential Surface Pressure: ~1139 psi (Based on 0.035 psi/ft gas gradient to surface) Applicable Frac Gradient: NA Cap string only, no new perforations Shallowest Allowable Perf TVD: NA – No perforations to be added Well Status: Gas producer making ~550 mcfd, ~80 bwpd @ 50-100psi, dropping 1 soap stick every 60 minutes. Brief Well Summary: BRU 242-04 was drilled and completed in 2012 as a Beluga G, H, I sands. It was subsequently fracture stimulated after the rig was moved off, but was shut in as a result of water production with little to no gas. It was then worked over in 2014 and the previous zones were isolated and the Sterling A thru the Beluga F sand were added, gravel packed and isolated with a packer & sleeves with a Superior completion system. Sterling A was opened in Jun 2018 and added 1.3 mmscfd and slowly declined. In November 2022 the well loaded with water. In October 2023 perforations were added through the gravel pack and rate increased until water loaded up in January 2024. In 2024 additional perforations were added through the gravel pack of sands that were not initially perforated during the gravel pack. Well is currently swinging ~75 psi on every soap drop and have to hold back pressure for sand production due to the swings on the well. The purpose of this work/sundry is to set a 3/8” stainless steel capillary string to inject liquid soap downhole and keep the well from slugging every time a soap stick is dropped. This well has a SCSSV that is currently not tested because there is no camp or housing within 660ft of the well. The SCSSSV will be bypassed and tagged Per 20AAC25.265(d)(4) the tubing retrievable SCSSSV will be bypassed while there is a capillary string installed in this well. Notes Regarding Wellbore Condition x 3.5” gravel pack completion x Well flows 80 bwpd x Inclination o Max deviation of 52° @ 1936’ MD Procedure: 1. Lockout/defeat SCSSSV (tag per 20AAC25.265) 2. Fill cap string with liquid foamer in string 3. RU Cap String Truck 4. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Remove soap launcher. Install pack-off and pressure test against swab valve to 1500 psi. 5. RIH with 3/8” capillary string to ±4,000’ MD. 6. Install slips and connect tubing to chemical injection pump. 7. Set spool of remaining line near well 8. RD cap string unit, and turn well over to production. Well Prognosis 9. Monitor results for a day, if soaping does not meet flow requirements, adjust depth of injection point and adjust rates of foamer injection to optimize rate. 10. Pump defoamer as needed into flowline downstream of wing valve. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. 660 ft Radius Map _____________________________________________________________________________________ Pg.1 Updated by CAH 06-23-25 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’ 6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry #Depth MD (ft.)ID (in.)Description 1 18’3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518’2.812 Camco TMAXX-5E SCSSV X Profile SN C-135-0852 3 3460’2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519’2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576’2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING/TUBING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''5130’' JEWELRY DETAIL –See Superior Schematic for more details *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are Gravel pack sleeves, not shiftable by slickline #Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Gravel pack Sleeve & circ valve 3778 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Superior Isolation Packer 7027 NI B5 3824 2.75 Gravel Pack Sleeve & circ valve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Superior Isolation Packer 7027 NI C5 3954 2.75 Gravel Pack Sleeve & circ valve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Superior Isolation Packer 7027 NI E5 4222 2.75 Gravel Pack Sleeve & circ valve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Gravel Pack Sleeve & circ valve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ _____________________________________________________________________________________ Pg.2 Updated by CAH 06-23-25 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 13' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 7/20/2012 Grvl Pck Beluga D1 4,237’ 4,241’ 3,710’ 3,714’ 4’ 3/13/24 Open Beluga D2 4,257’ 4,259’ 3,730’ 3,732’’ 2’ 3/13/24 Open Beluga D4 4,319’ 4,323’ 3,791’ 3,795’ 4’ 3/13/24 Open Beluga D6 4,378’ 4,382’ 3,849’ 3,853’ 4’ 3/13/24 Open Beluga D7 4,405’ 4,412’ 3,876’ 3,883’ 7’ 3/12/24 Open Beluga E1 4,453’ 4,466’ 3,923’ 3,936’ 13’ 3/12/24 Open Beluga E1 4,480’ 4,500’ 3,950’ 3,970’ 20’ 3/12/24 Open Beluga E 4,500' 4,514' 3,969' 3,983' 14' 7/20/2012 Grvl Pck Beluga E4 4,629’ 4,638’ 4,096’ 4,105’ 9’ 3/12/24 Open Beluga E5 4,645’ 4,652’ 4,112’ 4,119’ 7’ 3/12/24 Open Beluga E5 4,685’ 4,695’ 4,151’ 4,161’ 10’ 3/12/24 Open Beluga E 4,704' 4,714' 4,170' 4,180' 10' 7/20/2012 Grvl Pck Beluga E5 4,717’ 4,724’ 4,183’ 4,190’ 7’ 3/12/24 Open E6 4,745’ 4,754’ 4,210’ 4,219’ 9' 10/8/2023 Open E6 4,764’ 4,770’ 4,229’ 4,235’ 6' 10/8/2023 Open Beluga E6 4,777’ 4,784’ 4,242’ 4,249’ 7’ 3/12/24 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 9' 10/8/2023 Open Beluga F 4,970' 4,982' 4,432' 4,444' 12' 7/20/2012 Grvl Pck F6 5,018’ 5,023’ 4,479’ 4,484’ 5' 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 8' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 13' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 5' 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 4' 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 5' 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 14' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 16' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 16' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 20' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 5' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 11' 7/20/2012 Plugged _____________________________________________________________________________________ Pg.1 Updated by CAH 06-23-25 PROPOSED Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’ 6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry #Depth MD (ft.)ID (in.)Description 1 18’3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518’2.812 Camco TMAXX-5E SCSSV X Profile SN C-135-0852 3 3460’2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519’2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576’2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING/TUBING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''5130’' 3/8”Capillary string 0.08# 0.049 2205 duplex Swagelok 0.0895”±4,000’ JEWELRY DETAIL –See Superior Schematic for more details *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are Gravel pack sleeves, not shiftable by slickline #Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Gravel pack Sleeve & circ valve 3778 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Superior Isolation Packer 7027 NI B5 3824 2.75 Gravel Pack Sleeve & circ valve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Superior Isolation Packer 7027 NI C5 3954 2.75 Gravel Pack Sleeve & circ valve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Superior Isolation Packer 7027 NI E5 4222 2.75 Gravel Pack Sleeve & circ valve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Gravel Pack Sleeve & circ valve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ Cap String @ ~4,000’ (TBD) _____________________________________________________________________________________ Pg.2 Updated by CAH 06-23-25 PROPOSED Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 13' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 7/20/2012 Grvl Pck Beluga D1 4,237’ 4,241’ 3,710’ 3,714’ 4’ 3/13/24 Open Beluga D2 4,257’ 4,259’ 3,730’ 3,732’’ 2’ 3/13/24 Open Beluga D4 4,319’ 4,323’ 3,791’ 3,795’ 4’ 3/13/24 Open Beluga D6 4,378’ 4,382’ 3,849’ 3,853’ 4’ 3/13/24 Open Beluga D7 4,405’ 4,412’ 3,876’ 3,883’ 7’ 3/12/24 Open Beluga E1 4,453’ 4,466’ 3,923’ 3,936’ 13’ 3/12/24 Open Beluga E1 4,480’ 4,500’ 3,950’ 3,970’ 20’ 3/12/24 Open Beluga E 4,500' 4,514' 3,969' 3,983' 14' 7/20/2012 Grvl Pck Beluga E4 4,629’ 4,638’ 4,096’ 4,105’ 9’ 3/12/24 Open Beluga E5 4,645’ 4,652’ 4,112’ 4,119’ 7’ 3/12/24 Open Beluga E5 4,685’ 4,695’ 4,151’ 4,161’ 10’ 3/12/24 Open Beluga E 4,704' 4,714' 4,170' 4,180' 10' 7/20/2012 Grvl Pck Beluga E5 4,717’ 4,724’ 4,183’ 4,190’ 7’ 3/12/24 Open E6 4,745’ 4,754’ 4,210’ 4,219’ 9' 10/8/2023 Open E6 4,764’ 4,770’ 4,229’ 4,235’ 6' 10/8/2023 Open Beluga E6 4,777’ 4,784’ 4,242’ 4,249’ 7’ 3/12/24 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 9' 10/8/2023 Open Beluga F 4,970' 4,982' 4,432' 4,444' 12' 7/20/2012 Grvl Pck F6 5,018’ 5,023’ 4,479’ 4,484’ 5' 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 8' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 13' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 5' 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 4' 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 5' 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 14' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 16' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 16' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 20' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 5' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 11' 7/20/2012 Plugged S013N010W S012N010W Sec. 34 Sec. 3Sec. 4 BELUGA RIVER UNIT A029656 A029657 BRU-211-03 BHL BRU-224-34 BHL BRU-223-34 BRU-224-34 BRU-241-04XX BRU-211-03 BRU C PAD ADL 17592 ADL 17599 BRU-242-04 Anchorage Homer Nikiski Seward BRU 242-04 Legend BRU 242-04 660ft Radius Oil and Gas Unit Boundary Surface Well Locations Bottom Hole Locations Well Paths Private Lease Map Date: 6/23/2025 0130260 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxNAD 1927 StatePlane Alaska 4 FIPS 5004 Beluga River Unit BRU 242-04 Well 660-ft Radius u 1:4,000 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Daniel Taylor To:Regg, James B (OGC); McLellan, Bryan J (OGC) Cc:Chad Helgeson; Wyatt Rivard Subject:BRU 242-04 (PTD#: 212-041) SCSSSV Lock Open Date:Wednesday, June 25, 2025 8:49:05 AM Attachments:BRU 242-04_660ft Radius.pdf Jim / Bryan, BRU 242-04 (PTD#: 212-041) is not required to have a SCSSSV according to 20 AAC 25.265(d)(2)(A-H). BRU 242-04 does contain a SCSSSV in its jewelry and it did not pass its last test. We are going to lock open the SCSSSV on BRU 242-04. Attached is the map of this pad with a 660ft radius circle from BRU 242-04. Please let us know if you need any additional information on this well. Regards, Daniel Taylor, P.E. Well Integrity O: 907-777-8319 C: 907-947-8051 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. %HOXJD5LYHU8QLW 37' S013N010W S012N010W Sec. 34 Sec. 3Sec. 4 BELUGA RIVER UNIT A029656 A029657 BRU-211-03 BHL BRU-224-34 BHL BRU-223-34 BRU-224-34 BRU-241-04XX BRU-211-03 BRU C PAD ADL 17592 ADL 17599 BRU-242-04 Anchorage Homer Nikiski Seward BRU 242-04 Legend BRU 242-04 660ft Radius Oil and Gas Unit Boundary Surface Well Locations Bottom Hole Locations Well Paths Private Lease Map Date: 6/23/2025 0 130 260 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxNAD 1927 StatePlane Alaska 4 FIPS 5004 Beluga River Unit BRU 242-04 Well 660-ft Radius u 1:4,000 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Daniel Taylor To:Regg, James B (OGC); McLellan, Bryan J (OGC) Cc:Chad Helgeson; Wyatt Rivard Subject:BRU 242-04 (PTD#: 212-041) SCSSSV Lock Open Date:Wednesday, June 25, 2025 8:49:17 AM Attachments:BRU 242-04_660ft Radius.pdf Jim / Bryan, BRU 242-04 (PTD#: 212-041) is not required to have a SCSSSV according to 20 AAC 25.265(d)(2)(A-H). BRU 242-04 does contain a SCSSSV in its jewelry and it did not pass its last test. We are going to lock open the SCSSSV on BRU 242-04. Attached is the map of this pad with a 660ft radius circle from BRU 242-04. Please let us know if you need any additional information on this well. Regards, Daniel Taylor, P.E. Well Integrity O: 907-777-8319 C: 907-947-8051 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: 5/10/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240510-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 242-04 50283201640000 212041 3/11/2024 AK E-LINE Perf LRU C-01RD 50283200610100 201168 4/26/2024 AK E-LINE Perf LRU C-02 50283201900000 223057 4/28/2024 AK E-LINE Perf MPU F-65 50029227526000 223121 5/3/2024 AK E-LINE HoistCut MPU L-07 50029220280000 190037 4/26/2024 AK E-LINE Perf NCIU A-17 50883201880000 223031 4/28/2024 AK E-LINE GPT/Perf NCIU B-02 50883200900100 197210 4/29/2024 AK E-LINE PPROF NCIU B-02 50883200900100 197210 5/4/2024 AK E-LINE PPROF PAXTON 6 50133207070000 222054 4/13/2024 AK E-LINE GPT/CIBP/Perf PAXTON 6 50133207070000 222054 4/16/2024 AK E-LINE GPT/CIBP/Perf SRU 14B-27 50133206040000 212089 4/23/2024 AK E-LINE Caliper SRU 32C-15 50133206130000 213070 4/24/2024 AK E-LINE Caliper TBU M-15 50733204220000 190109 4/18/2024 AK E-LINE GPT/Puncher TBU M-23 50733207190000 224018 5/1/2024 AK E-LINE CBL Please include current contact information if different from above. T38780 T38781 T38782 T38783 T38784 T38785 T38786 T38786 T38787 T38787 T38788 T38789 T38790 T38791 BRU 242-04 50283201640000 212041 3/11/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 15:31:19 -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: 4/19/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240419 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 4/5/2024 AK E-Line Perf BRU 242-04 50283201640000 212041 3/20/2024 AK E-Line JB/PProf NCIU A-17 50883201880000 223031 3/27/2024 AK E-Line GPT/Perf PBU 05-02A 50029201440100 201241 4/6/2024 Halliburton PPROF PBU 09-35A 50029213140100 193031 4/9/2024 Halliburton RBT PBU 13-24A 50029207390100 204243 4/5/2024 Halliburton RBT PBU B-14A 50029203490100 209059 4/2/2024 Halliburton RBT PBU D-31B 50029226720200 212168 4/7/2024 Halliburton PERF SRU 222-33 50133207150000 223100 3/27/2024 AK E-Line CIBP/Perf SRU 224-10 50133101380100 222124 3/29/2024 AK E-Line CIBP/Perf SRU 241-33B 50133206960000 221053 4/2/2024 AK E-Line CIBP Please include current contact information if different from above T38718 T38719 T38720 T38721 T38722 T38723 T38724 T38725 T38726 T38727 T38728 BRU 242-04 50283201640000 212041 3/20/2024 AK E-Line JB/PProf Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.19 14:54:13 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,221 feet See Schematic feet true vertical 6,650 feet N/A feet Effective Depth measured 5,400 feet See Schematic feet true vertical 4,856 feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 3,616' MD 3,100' TVD 518' MD/TVD Packers and SSSV (type, measured and true vertical depth)See Schematic See Schematic See Schematic See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Jake Flora, Operations Engineer 324-115 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 203 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 jake.flora@hilcorp.com 907-777-8442 N/A Camco TMAXX-53 SSSV 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 10 Size 110' 98 102434 0 3015 156 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-041 50-283-20164-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029656 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 242-04 Plugs Junk measured Length Production Liner 7,192' Casing Structural 6,640'7,210' 110'Conductor Surface Intermediate 20" 9-5/8" 87' 3,317' 5,410psi 5,750psi 7,240psi 3,335'2,831' Burst Collapse 3,090psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Noel Nocas (4361) Digitally signed by Noel Nocas (4361) Date: 2024.03.22 12:37:11 -08'00' RBDMS JSB 040224 DSR-3/29/24 Page 1/1 Well Name: BRU 242-04 Report Printed: 3/20/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:3/12/2024 End Date: Report Number 1 Report Start Date 3/12/2024 Report End Date 3/13/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up, Pick up CCL/GPT & lube, Pressure test 250/2000-good, Run # 1 run in hole, Fluid @ 3270', Tag @ 4907', Pull out of hole logging, PIck up & run perfs guns to perf the following: BEL E6 (4777-4784), BEL E5 (4717-4724), BEL E5 (4685-4695), BEL E5 (4645-4652), BEL E5 (4629- 4638), BEL E1 (4480-4500), BEL E1 (4453-4466), BEL D7 (4405-4412), Rig off well for the night. Report Number 2 Report Start Date 3/13/2024 Report End Date 3/14/2024 Last 24hr Summary PJSM, Crew travel to location, Pick up Run #7 & lube, Pressure test 250/2000-good, Run in hole and perf the following zones: BEL D6 (4378-4382), BEL D4 (4319- 4323), BEL D2 (4257-4259), BEL D1 (4237-4241), Rig down & release AK Eline. Hand over to production Field: Beluga River Sundry #: 324-115 State: Alaska Rig/Service:Permit to Drill (PTD) #:212-041Permit to Drill (PTD) #:212-041 Wellbore API/UWI:50-283-20164-00-00 _____________________________________________________________________________________ Pg.1 Updated by DMA 03-20-24 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’ 6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry ID.Depth MD (ft.)ID (in.)Description 1 18 3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518 2.812 Camco TMAXX-5E SCSSV X Profile 3 3460 2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519 2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576 2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''3616' TUBING DETAILS 3.5"Work String 12.95#P-110 PH-6 2.75''3,616' JEWELRY DETAIL *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are frac sleeves, not shiftable by slickline ID.Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Frac Sleeve 3776 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Isolation Packer B5 3824 2.75 Frac Sleeve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Isolation Packer C5 3954 2.75 Frac Sleeve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Isolation Packer E5 4222 2.75 Frac Sleeve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Frac Sleeve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ _____________________________________________________________________________________ Pg.2 Updated by DMA 03-20-24 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 13' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 7/20/2012 Grvl Pck Beluga D1 4,237’ 4,241’ 3,710’ 3,714’ 4’ 3/13/24 Open Beluga D2 4,257’ 4,259’ 3,730’ 3,732’’ 2’ 3/13/24 Open Beluga D4 4,319’ 4,323’ 3,791’ 3,795’ 4’ 3/13/24 Open Beluga D6 4,378’ 4,382’ 3,849’ 3,853’ 4’ 3/13/24 Open Beluga D7 4,405’ 4,412’ 3,876’ 3,883’ 7’ 3/12/24 Open Beluga E1 4,453’ 4,466’ 3,923’ 3,936’ 13’ 3/12/24 Open Beluga E1 4,480’ 4,500’ 3,950’ 3,970’ 20’ 3/12/24 Open Beluga E 4,500' 4,514' 3,969' 3,983' 14' 7/20/2012 Grvl Pck Beluga E4 4,629’ 4,638’ 4,096’ 4,105’ 9’ 3/12/24 Open Beluga E5 4,645’ 4,652’ 4,112’ 4,119’ 7’ 3/12/24 Open Beluga E5 4,685’ 4,695’ 4,151’ 4,161’ 10’ 3/12/24 Open Beluga E 4,704' 4,714' 4,170' 4,180' 10' 7/20/2012 Grvl Pck Beluga E5 4,717’ 4,724’ 4,183’ 4,190’ 7’ 3/12/24 Open E6 4,745’ 4,754’ 4,210’ 4,219’ 9' 10/8/2023 Open E6 4,764’ 4,770’ 4,229’ 4,235’ 6' 10/8/2023 Open Beluga E6 4,777’ 4,784’ 4,242’ 4,249’ 7’ 3/12/24 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 9' 10/8/2023 Open Beluga F 4,970' 4,982' 4,432' 4,444' 12' 7/20/2012 Grvl Pck F6 5,018’ 5,023’ 4,479’ 4,484’ 5' 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 8' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 13' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 5' 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 4' 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 5' 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 14' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 16' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 16' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 20' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 5' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 11' 7/20/2012 Plugged 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): 7,221'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See Attached Schematic 6,650'5,400'4,856' Beluga River Sterling-Beluga Gas 20" 3.5" Beluga River Unit (BRU) 242-04CO 802 Same 6,640'7" ~1020 psi See Schematic 9-5/8" Size Will perfs require a spacing exception due to property boundaries? 7,210' Perforation Depth MD (ft): 7,192' See Attached Schematic 5,750psi 110'110' 3,335' 87' 3,317' MDLength 9.3# / L-80 TVD Burst 3,627' 7,240psi 2,831' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029656 212-041 50-283-20164-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: 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 Jake Flora, Operations Engineer Camco TMAXX-53 SSSV;518' MD/TVD; 3,617MD/3,101TVD; jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: March 7, 2024 Superior: CSHP-II Pkr; (4) 7027 Iso Pkrs; Perm Pkr 3,817MD/3,297TVD; 3,948MD3,426TVD; 4,216MD/3,690TVD; 4,729MD/4,195TVD; 5,121MD/4,581TVD m n P 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 4:17 pm, Feb 27, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.02.26 09:39:28 - 09'00' Noel Nocas (4361) 324-114 10-404 Perforate DSR-2/29/24BJM 2/29/24 SFD 2/28/2024*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.01 07:35:42 -09'00'3/1/24 Well Prognosis Well Name:BRU 242-04 API Number:50-283-20164-00-00 Current Status:Gas Producer Permit to Drill Number:212-041 First Call Engineer: Jake Flora (907) 777-8442 (O)(720) 988-5375 (M) Second Call Engineer: Chad Helgeson (907) 777-8420 (O)(907) 229-4824 (M) Maximum Expected BHP: ~1869 psi @ 4249’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1020 psi (Max expected BHP - gas to surface) Applicable Frac Gradient: .82 psi/ft using 15.7 ppg EMW FIT at the surface casing 6/12/12 Shallowest Allowable Perf TVD: MPSP/(0.82-0.1) = 1020 psi / 0.72 = 1416‘ TVD Top of Pool per CO 802:3647’ MD & 3131’ TVD Well Status: Online producer making 200 mcfd @ 19 psi, no water to surface (below unload rate) Brief Well Summary BRU 242-04 was drilled and completed in 2012 as a Beluga G, H, I sands. It was subsequently fracture stimulated after the rig was moved off, but was shut in as a result of water production with little to no gas. It was then worked over in 2014 and the previous zones were isolated and the Sterling A thru the Beluga F sand were added, gravel packed and isolated with a packer & sleeves with a Superior completion system. Sterling A was opened in Jun 2018 and added 1.3 mmscfd and slowly declined. In November 2022 the well loaded with water. In October 2023 perforations were added through the gravel pack and rate increased until water loaded up in January 2024. The purpose of this sundry is to increase production by perforating multiple infill Beluga sands. Notes Regarding Wellbore Condition: 2/11/24 SL DD Bailer tagged bottom at 4920’ & Ran PT survey in well, FL @ 3,091ft, current BHP-715 psi Procedure 1. RU E-line, PT lubricator to 2000 psi 2. Perforate Beluga sands from the bottom up within the below interval: Sand MD TOP MD BASE TVD TOP TVD BASE Footage Beluga D1 ±4,237’ ±4,241’ ±3,710’ ±3,714’ ±4’ Beluga D2 ±4,257’ ±4,259’ ±3,730’ ±3,732’’ ±2’ Beluga D4 ±4,319’ ±4,323’ ±3,791’ ±3,795’ ±4’ Beluga D6 ±4,378’ ±4,382’ ±3,849’ ±3,853’ ±4’ Beluga D7 ±4,405’ ±4,412’ ±3,876’ ±3,883’ ±7’ Beluga E1 ±4,453’ ±4,466’ ±3,923’ ±3,936’ ±13’ Beluga E1 ±4,480’ ±4,500’ ±3,950’ ±3,970’ ±20’ Beluga E4 ±4,629’ ±4,638’ ±4,096’ ±4,105’ ±9’ Beluga E5 ±4,645’ ±4,652’ ±4,112’ ±4,119’ ±7’ Beluga E5 ±4,685’ ±4,695’ ±4,151’ ±4,161’ ±10’ Beluga E5 ±4,717’ ±4,724’ ±4,183’ ±4,190’ ±7’ Beluga E6 ±4,777’ ±4,784’ ±4,242’ ±4,249’ ±7’ 3647’ MD & 3131’ TVD y perforating multiple infill Beluga sands. Top of Pool Well Prognosis a) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic _____________________________________________________________________________________ Pg.1 Updated by DMA 11-01-23 SCHEM ATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’ 6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry ID. Depth MD (ft.) ID (in.) Description 1 18 3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518 2.812 Camco TMAXX-5E SCSSV X Profile 3 3460 2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519 2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576 2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''3616' TUBING DETAILS 3.5"Work String 12.95#P-110 PH-6 2.75''3,616' JEWELRY DETAIL *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are frac sleeves, not shiftable by slickline ID. Depth MD (ft.) ID (in.) Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Frac Sleeve 3776 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Isolation Packer B5 3824 2.75 Frac Sleeve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Isolation Packer C5 3954 2.75 Frac Sleeve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Isolation Packer E5 4222 2.75 Frac Sleeve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Frac Sleeve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ _____________________________________________________________________________________ Pg.2 Updated by DMA 11-01-23 SCHEM ATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 7/20/2012 Grvl Pck Beluga E 4,500' 4,514' 3,969' 3,983' 7/20/2012 Grvl Pck Beluga E 4,704' 4,714' 4,170' 4,180' 7/20/2012 Grvl Pck E6 4,745’ 4,754’ 4,522’ 4,531’ 10/8/2023 Open E6 4,764’ 4,770’ 4,541’ 4,547’ 10/8/2023 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7/20/2012 Grvl Pck Beluga F 4,970' 4,982' 4,432' 4,444' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 10/8/2023 Open F6 5,018’ 5,023’ 4,479’ 4,484’ 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 7/20/2012 Plugged _____________________________________________________________________________________ Pg.1 Updated by DMA 02-22-24 PROPOSED Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1, 3617’ B3, 3817’ B5 C3, 3948’ C5 E3, 4216’ E5 F4, 4729’ A B B C C D E F P1, 5121’ Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ P2, CIBP w cmt top @ 5400’6 9 TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ 7” P3 G, H, I F7 Sands shot 5277-82’, 5267-71’ 5226-31’ Jewelry ID.Depth MD (ft.)ID (in.)Description 1 18 3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518 2.812 Camco TMAXX-5E SCSSV X Profile 3 3460 2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519 2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576 2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''3616' TUBING DETAILS 3.5"Work String 12.95#P-110 PH-6 2.75''3,616' JEWELRY DETAIL *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are frac sleeves, not shiftable by slickline ID.Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Frac Sleeve 3776 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Isolation Packer B5 3824 2.75 Frac Sleeve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Isolation Packer C5 3954 2.75 Frac Sleeve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Isolation Packer E5 4222 2.75 Frac Sleeve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Frac Sleeve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed 2/11/24 tag 4920’ _____________________________________________________________________________________ Pg.2 Updated by DMA 02-22-24 PROPOSED Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Ft Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 13' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 7/20/2012 Grvl Pck Beluga D1 ±4,237’ ±4,241’ ±3,710’ ±3,714’ ±4’ Proposed TBD Beluga D2 ±4,257’ ±4,259’ ±3,730’ ±3,732’’ ±2’ Proposed TBD Beluga D4 ±4,319’ ±4,323’ ±3,791’ ±3,795’ ±4’ Proposed TBD Beluga D6 ±4,378’ ±4,382’ ±3,849’ ±3,853’ ±4’ Proposed TBD Beluga D7 ±4,405’ ±4,412’ ±3,876’ ±3,883’ ±7’ Proposed TBD Beluga E1 ±4,453’ ±4,466’ ±3,923’ ±3,936’ ±13’ Proposed TBD Beluga E1 ±4,480’ ±4,500’ ±3,950’ ±3,970’ ±20’ Proposed TBD Beluga E 4,500' 4,514' 3,969' 3,983' 14' 7/20/2012 Grvl Pck Beluga E4 ±4,629’ ±4,638’ ±4,096’ ±4,105’ ±9’ Proposed TBD Beluga E5 ±4,645’ ±4,652’ ±4,112’ ±4,119’ ±7’ Proposed TBD Beluga E5 ±4,685’ ±4,695’ ±4,151’ ±4,161’ ±10’ Proposed TBD Beluga E 4,704' 4,714' 4,170' 4,180' 10' 7/20/2012 Grvl Pck Beluga E5 ±4,717’ ±4,724’ ±4,183’ ±4,190’ ±7’ Proposed TBD E6 4,745’ 4,754’ 4,522’ 4,531’ 9' 10/8/2023 Open E6 4,764’ 4,770’ 4,541’ 4,547’ 6' 10/8/2023 Open Beluga E6 ±4,777’ ±4,784’ ±4,242’ ±4,249’ ±7’ Proposed TBD Beluga F 4,830' 4,837' 4,294' 4,301' 7' 7/20/2012 Grvl Pck F4 4,905’ 4,914’ 4,368’ 4,377’ 9' 10/8/2023 Open Beluga F 4,970' 4,982' 4,432' 4,444' 12' 7/20/2012 Grvl Pck F6 5,018’ 5,023’ 4,479’ 4,484’ 5' 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 8' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 13' 7/20/2012 Grvl Pck F7 5,226’ 5,231’ 4,684’ 4,689’ 5' 10/7/2023 Open F7 5,267’ 5,271’ 4,724’ 4,728’ 4' 10/7/2023 Open F7 5,277’ 5,282’ 4,734’ 4,738’ 5' 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 14' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 16' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 16' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 20' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 5' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 11' 7/20/2012 Plugged 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,221 feet See Schematic feet true vertical 6,650 feet N/A feet Effective Depth measured 5,400 feet See Schematic feet true vertical 4,856 feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 3,627' MD 518' MD/TVD Packers and SSSV (type, measured and true vertical depth) See Schematic See Schematic See Schematic See Schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5,410psi 5,750psi 7,240psi 3,335' 2,831' Burst Collapse 3,090psi Production Liner 7,192' Casing Structural 6,640'7,210' 110'Conductor Surface Intermediate 20" 9-5/8" 87' 3,317' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-041 50-283-20164-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA029656 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 242-04 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 110' 105 01927 0 211 145 Jake Flora, Operations Engineer 323-522 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 181 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 jake.flora@hilcorp.com 907-777-8442 N/A Camco TMAXX-53 SSSV p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:15 pm, Nov 08, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.11.08 11:22:49 - 09'00' Noel Nocas (4361) Rig Start Date End Date 10/7/23 10/8/23 10/07/2023 - Saturday PJSM, travel to K pad, start up and warm up equipment, rig down and pack up. Move equipment f/ K pad to C pad. Make up 4-1/16 tree flange and nipple up riser x/over joint, travel with man lift. Rig up E-line Equpment, take perf gun apart and re-wire same. Pick up guns. Pressure test lubricator to 250 low and 2500 psi High, had to change out needle on lubricator, tighten flange on Otis tree flange. RIH with 2-3/8 switch gun with 5", 4' & 5 ft. Loaded with 6 spf at 60 pashing. to 5,330' ELM, log gun on depth perf the Beluga F7 sand f/ 5,277' to 5,282', initial pressure 240, 5-minute 241.7 psi, 10-minute reading 241.7 psi, 15-minute 241.7 psi, perf the Beluga F7 sand from 5.267' to 5,271', initial pressure 241.7, 5-minute reading 242, psi, 10-minute 243 psi, 15-minute reading 244 psi, perf the Beluga F7 sand f/ 5226' to 5231' initial pressure 244 psi, 5-minute reading 262 psi, 10-minute reading 272 psi, 15-minute reading 285 psi pooh with spent guns. OOH, pressure at 340 psi. Lad down guns (all shots fired). 10/08/2023 - Sunday PJSM, travel to C pad, start up and warm up equipment. Rig up and arm switch gun, stab on RIH lost communication with bottom gun Pooh. Trouble shoot switch guns found wire grounded to barrel. Rih with 5 and 9' switch gun loaded with 5 spf at 60 phasing, log guns on depth perf the F6 sand f/ 5018' to 5023', initial pressure 548 psi, 5-minute 537 psi, 10- minute reading 533 psi, 15-minute reading 534 psi. Pick up and perf the Beluga F4 sand f/ 4905 to 4914' initial pressure 534 psi, 5-minute reading 537 psi, 10-minute reading 533 psi, 15-minute reading 534 psi pooh lay down gun all shots fired. Change out perf guns. Pick up 2-3/8 7 ft. and 12 ft. switch guns loaded the 5 spf at 60 phasing RIH log guns on depth perf the Beluga E6 sand f/ 4764 to 4770' initial pressure 546 psi, 5-minute reading 557 psi, 10-minute reading 560 psi, 15-minute reading 559 psi p/up & perf the Beluga E6 sand from 4745 to 4754' initial pressure 559 psi, 5 minute reading 564 psi, 10 minute reading5 566 psi, 15 minute 565 psi, pooh lay down gun all shots fired. Rig down E- line equipment and pack up same. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 242-04 50-283-20164-00-00 212-041 Pick up and perf the Beluga F4 sand f/ 4905 to 4914' initial pressure 534 reading 244 psi, perf the Beluga F7 sand f/ 5226' to 5231' initial pressure 244 psi, 5-minute reading 262 psi, 10-minu spf at 60 phasing, log guns on depth perf the F6 sand f/ 5018' to 5023', initial pressure 548 psi, 5-minute 537 psi, 10- pashing. to 5,330' ELM, log gun on depth perf the Beluga F7 sand f/ 5,277' to 5,282', initial pressure 240, 5-minute 241.7 241.7 psi, perf the Beluga F7 sand from 5.267' to 5,271', initial pressure guns on depth perf the Beluga E6 sand f/ 4764 to 4770' reading 560 psi, 15-minute reading 559 psi p/up & perf the Beluga E6 sand from 4745 to 4754' in _____________________________________________________________________________________ Pg.1 Updated by DMA 11-01-23 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 20 9-5/8 RKB to MSL = 111 RKB to GL = 18 TOC @ 3,147 1 2 3 4 5 A1, 3617 B3, 3817 B5 C3, 3948 C5 E3, 4216 E5 F4, 4729 A B B C C D E F P1, 5121 Sleeve #2 3909 Sleeve #1 3776 Sleeve #3 4056 Sleeve #4 4177 Sleeve #5 4505 Sleeve #6 4690 Sleeve #7 4837 Sleeve #8 4960 Sleeve #9 5063 P2, CIBP w cmt top @ 54006 9 TD = 7,221 TVD = 6,650 PBTD = 7,221 ED = 5,400 ETVD = 4,855 7 P3 G, H, I F7 Sands shot 5277-82, 5267-71 5226-31 Jewelry ID. Depth MD (ft.) ID (in.) Description 1 18 3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518 2.812 Camco TMAXX-5E SCSSV X Profile 3 3460 2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519 2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576 2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 - Bridge plug w/ Cement to 5400' P3 5,536 - PXN plug CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''3616' TUBING DETAILS 3.5"Work String 12.95#P-110 PH-6 2.75''3,616' JEWELRY DETAIL *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are frac sleeves, not shiftable by slickline ID. Depth MD (ft.) ID (in.) Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Frac Sleeve 3776 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Isolation Packer B5 3824 2.75 Frac Sleeve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Isolation Packer C5 3954 2.75 Frac Sleeve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Isolation Packer E5 4222 2.75 Frac Sleeve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Frac Sleeve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed _____________________________________________________________________________________ Pg.2 Updated by DMA 11-01-23 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 7/20/2012 Grvl Pck Beluga E 4,500' 4,514' 3,969' 3,983' 7/20/2012 Grvl Pck Beluga E 4,704' 4,714' 4,170' 4,180' 7/20/2012 Grvl Pck E6 4,745 4,754 4,522 4,531 10/8/2023 Open E6 4,764 4,770 4,541 4,547 10/8/2023 Open Beluga F 4,830' 4,837' 4,294' 4,301' 7/20/2012 Grvl Pck Beluga F 4,970' 4,982' 4,432' 4,444' 7/20/2012 Grvl Pck F4 4,905 4,914 4,368 4,377 10/8/2023 Open F6 5,018 5,023 4,479 4,484 10/8/2023 Open Beluga F 5,035' 5,043' 4,496' 4,504' 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4,550' 4,563' 7/20/2012 Grvl Pck F7 5,226 5,231 4,684 4,689 10/7/2023 Open F7 5,267 5,271 4,724 4,728 10/7/2023 Open F7 5,277 5,282 4,734 4,738 10/7/2023 Open Beluga G 5,620' 5,634' 5,072' 5,086' 7/20/2012 Plugged Beluga G 5,750' 5,766' 5,200' 5,215' 7/20/2012 Plugged Beluga H 6,190' 6,206' 5,634' 5,650' 7/20/2012 Plugged Beluga H 6,260' 6,280' 5,703' 5,723' 7/20/2012 Plugged Beluga H 6,300' 6,305' 5,742' 5,747' 7/20/2012 Plugged Beluga I 7,100' 7,111' 6,530' 6,541' 7/20/2012 Plugged 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: 11/01/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231101 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 10/10/2023 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/21/2023 AK E-LINE Plug/Perf BRU 242-04 50283201640000 212041 10/13/2023 AK E-LINE Perf/PL KBU 43-07Y 50133206250000 214019 10/6/2023 AK E-LINE CIBP/Perf MPU L-62 50029236850000 220059 10/18/2023 HALLIBURTON MFC24 PBU 06-20B 50029207990200 223075 10/19/2023 HALLIBURTON RBT PBU W-26A 50029219640100 199081 12/16/2022 AK E-LINE CBL Please include current contact information if different from above. T38113 T38113 T38114 T38115 T38116 T38117 T38118 11/1/2023 BRU 242-04 50283201640000 212041 10/13/2023 AK E-LINE Perf/PL Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.01 14:36:12 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Jacob Flora Subject:RE: BRU 242-04 (10-403 323-522) (PTD 212-041) - Request to extend approved perf zone Date:Friday, September 29, 2023 2:15:00 PM Attachments:image006.png image008.png image009.png image010.png Jake, Hilcorp has approval to proceed with additional perfs under the existing open sundry 323-522. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Jacob Flora <Jake.Flora@hilcorp.com> Sent: Friday, September 29, 2023 11:22 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BRU 242-04 (10-403 323-522) (PTD 212-041) - Request to extend approved perf zone Hi Bryan, Hilcorp requests to add more perfs to the approved sundry. They are above the existing approved perfs, but below the top current open perf. Gross Interval MD TVD Existing Open 3737 – 5103’ 3220 – 4505’ Requesting to Add 4237 – 4770’ 3710 – 4235’ Currently Approved 4905 – 5282’ 4368 – 4738’ Please advise if you would like to see additional data in this request- Thanks for your time, Jake Requesting to Add Currently Approved 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): 7,221'N/A Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See Attached Schematic 6,650'5,400'4,856' Beluga River Sterling-Beluga Gas 20" Beluga River Unit (BRU) 242-04CO 802 Same 6,640'7" ~1,611 psi See Schematic 9-5/8" 3.5" 7,210' Perforation Depth MD (ft): 7,192' See Attached Schematic 5,750psi 110'110' 3,335' Size 87' 3,317' MDLength 9.3# / L-80 TVD Burst 3,627' 7,240psi 2,831' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA029656 212-041 50-283-20164-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: 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 Jake Flora, Operations Engineer Camco TMAXX-53 SSSV;518' MD/TVD; 3,617MD/3,101TVD; jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: September 28, 2023 Superior: CSHP-II Pkr; (4) 7027 Iso Pkrs; Perm Pkr 3,817MD/3,297TVD; 3,948MD3,426TVD; 4,216MD/3,690TVD; 4,729MD/4,195TVD; 5,121MD/4,581TVD m n P s 66 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:39 am, Sep 15, 2023 323-522 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.09.14 17:37:07 - 08'00' Noel Nocas (4361) MDG 9/18/2023 10-404 BJM 9/22/23 DSR-9/15/23*&:JLC 9/25/2023 09/25/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.09.25 09:25:16 -08'00' RBDMS JSB 092623 Well Prognosis Well Name:BRU 242-04 API Number:50-283-20164-00-00 Current Status:Gas Producer Permit to Drill Number:212-041 First Call Engineer:Jake Flora (907) 777-8442 (O)(720) 988-5375 (M) Second Call Engineer:Chad Helgeson (907) 777-8420 (O)(907) 229-4824 (M) Maximum Expected BHP: ~2084 psi @ 4738’ TVD (0.44 psi/ft gradient to bottom perf) Max. Potential Surface Pressure: ~1611 psi (Max expected BHP - gas to surface) Well Status: Online producer making 170 mcfd @ 19 psi, no water to surface (below unload rate) Brief Well Summary BRU 242-04 was a stable producer that fell below unload rate in November 2022 and has seen a steady decline since. The purpose of this sundry is to increase production by perforating multiple infill Beluga and Sterling sands. Notes Regarding Wellbore Condition: 9/12-13/2023 Tag TD at 5400’ (CIBP). Swab 50 bwpd for two days. Initial fluid level at 2850’, final fluid level at 4000’. Unable to kick off. Procedure 1. RU E-line, PT lubricator to 2500 psi 2. Perforate Beluga sands from the bottom up within the below interval: Sand MD TOP MD BASE TVD TOP TVD BASE Footage Beluga F4 4905’ 4914’ 4368’ 4377’ 9’ Beluga F6 5018’ 5023’ 4479’ 4484’ 5’ Beluga F7 5226’ 5231’ 4684’ 4689’ 5’ Beluga F7 5267’ 5271’ 4724’ 4728’ 4’ Beluga F7 5277’ 5282’ 4734’ 4738’ 5’ a) If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic y perforating multiple infill Beluga and Sterling sands. _____________________________________________________________________________________ Pg.1 JMF 03/23/2023 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1 B3 C3 E3 F4 Sterling Sands A B B C C C D D D Beluga Sands E E E E E E F F F F P1 11/26/16 E-Sands only. Pumped 1000 gal MeOH and bullheaded gas. Well flowed back. F-Sands believed to be Gas. -JEK Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ Jewelry ID. Depth MD (ft.) ID (in.) Description 1 18 3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518 2.812 Camco TMAXX-5E SCSSV X Profile 3 3460 2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519 2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576 2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''3616' TUBING DETAILS 3.5"Work String 12.95#P-110 PH-6 2.75''3,616' JEWELRY DETAIL *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are frac sleeves, not shiftable by slickline Gravel Pack A Interval ID. Depth MD (ft.) ID (in.) Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Frac Sleeve 3776 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Isolation Packer B5 3824 2.75 Frac Sleeve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Isolation Packer C5 3954 2.75 Frac Sleeve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Isolation Packer E5 4222 2.75 Frac Sleeve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Frac Sleeve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed F21 5113 2 775 RkSlDCi l 7027 VI /BU _____________________________________________________________________________________ Pg.2 Created By: JMF 9-13-23 SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 7” TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ Max Angle = 52.3 deg @ 1,937’ 6 9 G G H H H I P2 P3 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Sterling A 3,737' 3,751' 3,220' 3,232' 14' 21 7/20/2012 Grvl Pck Sterling A 3,788' 3,803' 3,269' 3,283' 15' 21 7/20/2012 Grvl Pck Sterling B 3,882' 3,901' 3,361' 3,380' 19' 21 7/20/2012 Grvl Pck Sterling B 3,909' 3,932' 3,388' 3,410' 23' 21 7/20/2012 Grvl Pck Sterling C 4,017' 4,034' 3,494' 3,511' 17' 21 7/20/2012 Grvl Pck Sterling C 4,086' 4,118' 3,562' 3,593' 32' 21 7/20/2012 Grvl Pck Sterling D 4,150' 4,161' 3,625' 3,635' 11' 21 7/20/2012 Grvl Pck Sterling D 4,187' 4,196' 3,661' 3,670' 9' 21 7/20/2012 Grvl Pck Beluga E 4,500' 4,514' 3969' 3983' 14 21 7/20/2012 Grvl Pck Beluga E 4,704' 4,714' 4170' 4180' 10 21 7/20/2012 Grvl Pck Beluga F 4,830' 4,837' 4294' 4301' 7 21 7/20/2012 Grvl Pck Beluga F 4,970' 4,982' 4432' 4444' 12 21 7/20/2012 Grvl Pck Beluga F 5,035' 5,043' 4496' 4504' 7 21 7/20/2012 Grvl Pck Beluga F 5,090' 5,103' 4550' 4563' 13 21 7/20/2012 Grvl Pck Beluga G 5,620' 5,634' 5072' 5086' 14 5 7/20/2012 Plugged Beluga G 5,750' 5,766' 5200' 5215' 16 5 7/20/2012 Plugged Beluga H 6,190' 6,206' 5634' 5650' 16 5 7/20/2012 Plugged Beluga H 6,260' 6,280' 5703' 5723' 20 5 7/20/2012 Plugged Beluga H 6,300' 6,305' 5742' 5747' 5 5 7/20/2012 Plugged Beluga I 7,100' 7,111' 6530' 6541' 11 5 7/20/2012 Plugged _____________________________________________________________________________________ Pg.1 Updated by: DMA 09-14-23 PROPOSED SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 20” 9-5/8” RKB to MSL = 111’ RKB to GL = 18’ TOC @ 3,147’ 1 2 3 4 5 A1 B3 C3 E3 F4 Sterling Sands A B B C C C D D D Beluga Sands E E E E E E F F F F P1 11/26/16 E-Sands only. Pumped 1000 gal MeOH and bullheaded gas. Well flowed back. F-Sands believed to be Gas. -JEK Sleeve #2 3909’ Sleeve #1 3776’ Sleeve #3 4056’ Sleeve #4 4177’ Sleeve #5 4505’ Sleeve #6 4690’ Sleeve #7 4837’ Sleeve #8 4960’ Sleeve #9 5063’ Jewelry ID.Depth MD (ft.)ID (in.)Description 1 18 3.9 Vetco Tbg. Hanger Gray MB-230 10.875" x4.5" 2 518 2.812 Camco TMAXX-5E SCSSV X Profile 3 3460 2.92 Camco KBMG-LTS w/ CM-40R Chem Valve 4 3519 2.915 Camco MMG GLM w/ DCR-1-SV-RKP Latch 5 3576 2.813 HES 'X' Nipple 6 5436 3.725 Halliburton 'XN' Nipple 9 5501 3 Seal Assembly Mule Shoe Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 5,121 4 Perm. Packer 7"x4" 26-29# NI Wicker Slips P2 5,450 -Bridge plug w/ Cement to 5400' P3 5,536 -PXN plug CASING DETAIL Size Type WT Grade Conn ID Btm 20''Conductor 165#H-40 Weld 18.75''110' 9-5/8"Surface 40#L-80 BTCm 8.835''3335' 7''Production 26#L-80 BTCM 6.276''7210' 3.5''Tubing 9.3#L-80 EUE 8RD 2.992''3616' TUBING DETAILS 3.5"Work String 12.95#P-110 PH-6 2.75''3,616' JEWELRY DETAIL *Orange Sleeves are Superior and shiftable (9 total) *Gray sleeves are frac sleeves, not shiftable by slickline Gravel Pack A Interval ID.Depth MD (ft.)ID (in.)Description A1 3617 4 Superior CSHP-II Packer A5 3656 2.75 Frac Sleeve 3776 2.83 Sleeve #1, Position 2, Open 5/30/18 B3 3817 2.816 Isolation Packer B5 3824 2.75 Frac Sleeve 3909 2.83 Sleeve #2, Position 2, Closed 3/19/22 C3 3948 2.816 Isolation Packer C5 3954 2.75 Frac Sleeve 4056 2.83 Sleeve #3, Position 2, Closed 3/21/22 4177 2.75 Sleeve #4, Position 2, Closed E3 4216 2.816 Isolation Packer E5 4222 2.75 Frac Sleeve 4505 2.83 Sleeve #5, Position 4, Open 4690 2.83 Sleeve #6, Position 4, Closed F4 4729 2.816 Isolation Packer F6 4735 2.75 Frac Sleeve 4837 2.83 Sleeve #7, Position 4, Closed 4960 2.83 Sleeve #8, Position 4, Closed 5063 2.83 Sleeve #9, Position 4, Closed F21 5113 2.775 Rocker Style De-Crippler 7027 VI w/BU _____________________________________________________________________________________ Pg.2 Updated by: DMA 09-14-23 PROPOSED SCHEMATIC Beluga River Unit Well: BRU 242-04 Last Completed: 7/5/2014 PTD: 212-041 API: 50-283-20164-00 7” TD = 7,221’ TVD = 6,650’ PBTD = 7,221’ ED = 5,400’ ETVD = 4,855’ Max Angle = 52.3 deg @ 1,937’ 6 9 G G H H H I P2 P3 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status Sterling A 3,737'3,751'3,220'3,232'14'21 7/20/2012 Grvl Pck Sterling A 3,788'3,803'3,269'3,283'15'21 7/20/2012 Grvl Pck Sterling B 3,882'3,901'3,361'3,380'19'21 7/20/2012 Grvl Pck Sterling B 3,909'3,932'3,388'3,410'23'21 7/20/2012 Grvl Pck Sterling C 4,017'4,034'3,494'3,511'17'21 7/20/2012 Grvl Pck Sterling C 4,086'4,118'3,562'3,593'32'21 7/20/2012 Grvl Pck Sterling D 4,150'4,161'3,625'3,635'11'21 7/20/2012 Grvl Pck Sterling D 4,187'4,196'3,661'3,670'9'21 7/20/2012 Grvl Pck Beluga E 4,500'4,514'3,969'3,983'14'21 7/20/2012 Grvl Pck Beluga E 4,704'4,714'4,170'4,180'10'21 7/20/2012 Grvl Pck Beluga F 4,830'4,837'4,294'4,301'7'21 7/20/2012 Grvl Pck Beluga F 4,970'4,982'4432'4,444'12'21 7/20/2012 Grvl Pck Beluga F4 ±4,905’±4,914’±4,368’±4,377’±9’Proposed TBD Beluga F6 ±5,018’±5,023’±4,479’±4,484’±5’Proposed TBD Beluga F 5,035'5,043'4,496'4,504'7'21 7/20/2012 Grvl Pck Beluga F 5,090'5,103'4,550'4,563'13'21 7/20/2012 Grvl Pck Beluga F7 ±5,226’±5,231’±4,684’±4,689’±5’Proposed TBD Beluga F7 ±5,267’±5,271’±4,724’±4,728’±4’Proposed TBD Beluga F7 ±5,277’±5,282’±4,734’±4,738’±5’Proposed TBD Beluga G 5,620'5,634'5,072'5,086'14'5 7/20/2012 Plugged Beluga G 5,750'5,766'5,200'5,215'16'5 7/20/2012 Plugged Beluga H 6,190'6,206'5,634'5,650'16'5 7/20/2012 Plugged Beluga H 6,260'6,280'5,703'5,723'20'5 7/20/2012 Plugged Beluga H 6,300'6,305'5,742'5,747'5'5 7/20/2012 Plugged Beluga I 7,100'7,111'6,530'6,541'11'5 7/20/2012 Plugged Hilntrp .;It�Ml:a, 1.6C.. DATE 3/27/2019 1 041 Debra Oudean Hilcorp Alaska, LLC 30 5 12 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 71h Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 242-04(212-041) CD: Mj BRU-242-04 PPROF_03MAY18 6/27120181:15 PM ® BRLJ_242-01_WaterConformance03MAY... 5/29/20184:19 PM BRU 242-04_WaterConformance 03MAY... 5/29/2018 9:33 AM BRU 242-04 WaterConforrnance_Compo... 5/221201 8 1 P. 12 AM BRU_242-04 ViaterConformance_Compo... 51221'2018 iQ:14 AM RECEIVE® MAR 2 8 2019 AOGCC LAS File 3,302 KB PDF Document 5,753 KB Microsoft Powe&_ 3,632 KB DLIS File 11,582 KB LAS File 614 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Gat ZAz-o4 Pr zt2.0410 Regg, James B (DOA) From: Arctic Fox Company Man 2014 [ArcticFoxCompanyMan2014@conocophillips.com] Sent: Monday, June 23, 2014 8:29 AM To: Huck, Drew; Shields, Austin J Cc: Regg, James B (DOA) Subject: Test Chart for Permanent packer Attachments: Perm Packer Under Sump Packer Test Chart 242-04 6-23-14.pdf Drew, Here is the test Chart for the permanent packer we set last night. Thank you, Scott Heim/ RandyDolcater Arctic Fox Company Man Beluga River Unit 907-263-3010 1 • 111. 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I** \‘'0' ,, ,,*,, \\ - -ste,c,,ett. ... -. /0# .---.. t.ot-usz-g---Arets ,..., , 11:1 iii 1 44 4,44,/,t,'We.X-'- */*/ / 4:rfte i. if �'�► ,r,U'�„y,,„:2,4400 �E '� tyarillti;;;;Iiii\t\\ ��i+nig r'►IlftNmi��ei H. c{ • i •�� IIIIIIOII)�I IIN�Igq� I nIIIIIIIyNII11NiHu � .� � �� . a!� aI 1 JIM rill ilia Mw�ftianuu��eaHu,��u� N 11111111Il�IMIN MMMO,u�«p ,�-., �}• �� .■��ru�,kli�ti��11100VOMOVIN‘ , e `'.<4' ji/ 44111110 1011111111111011111111111141111111141 u��nJ11 d I wpaOSO*A$41to S , _a, n 111 ,j,v447,4„,_ At /AWIP1i*4 #14 '*'Ø*' i =__ as ` °I*/ 0 � trill'� iii r�Gi4 i i,*ak, Nw •,,444,t4t $&,..#...4 4.----"Agit:El.. .S-- _01, � ..' / , VI,- '�, N 4� � fir � g--1-441111 ��i r eft -•- • I `.'' 4741--44-..-: t-4Z =%'sem'i ,i'.• s . ,.„... .. ...,...,.„____=___„....,..„-____,.„.....,..___...�o DATA SUBMITTAL COMPLIANCE REPORT 10/9/2013 Permit to Drill 2120410 Well Name/No. BELUGA RIV UNIT 242-04 Operator CONOCOPHILLIPS ALASKA INC API No. 50-283-20164-00-00 MD 7221 TVD 6650 Completion Date 7/7/2012 Completion Status 1-GAS Current Status 1-GAS UIC No REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye/ DATA INFORMATION Types Electric or Other Logs Run: GR/RES,CBL (data taken from Logs Portion of Master Well Data Maint) Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Log Mud Loge' 2 Col 3346 7221 Open 1/11/2013 MD Formation Evaluation Log Log Mud Log 2 Col 2838 6649 Open 1/11/2013 TVD Formation Evaluation Log Log Mud Log: 5 Col 3346 7221 Open 1/11/2013 MD Formation Evaluation Log Log Mud Log 2 Col 3346 7221 Open 1/11/2013 MD Drilling Engineering Log i ED C Las Report: Final Well RE 0 0 Open 1/18/2013 Surface Data Logging End of Well Report LAS PDF TIFF EMF Rpt Report: Final Well Re 0 7221 Open 1/18/2013 Surface Data Logging End of Well Report Log / 21772 Cement Bond 5 Col 3060 7116 Case 8/14/2012 MDD Advanced Cement Evaluation Logue 21772 Cement Bond 5 Col 0 7113 Case 8/14/2012 (4'6 CBL-M Log / 21772 See Notes 5 Col 0 7113 Case 8/14/2012 Circumferential Acoustic Scanning Tool (Cast-M) ED Tf 21772 Cement Evaluation 5 0 7113 Case 8/14/2012 Advanced Cement Evaluation,CBL-M,& III Circumferential Acoustic Scanning Tool(Cast-M) +Graphics tiff, las,dlis ED C as 21789 See Notes 0 0 Case 8/14/2012 Reservoir Description Tool RDT-A+Graphics tiff,las Log / 21804 Induction/Resistivity 25 Col 217 7221 Open 8/14/2012 416 ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity t, CTN Compensated Thermal Neutron Log 21804 Induction/Resistivity 25 Col 106 6539 Open 8/14/2012 'DWD SS ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron AOGCC Page 1 of 3 Wednesday,October 09,2013 DATA SUBMITTAL COMPLIANCE REPORT 10/9/2013 Permit to Drill 2120410 Well Name/No. BELUGA RIV UNIT 242-04 Operator CONOCOPHILLIPS ALASKA INC API No. 50-283-20164-00-00 MD 7221 TVD 6650 Completion Date 7/7/2012 Completion Status 1-GAS Current Status 1-GAS UIC No Log 21804 Induction/Resistivity 25 Col 217 7221 Open 8/14/2012 BAT Bi-Modal Acoustic DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron Log 21804 Induction/Resistivity 25 Col 106 6539 Open 8/14/2012 Ty,• SS BAT Bi-Modal Acoustic 1116GR Dual Gamma Ray EWR Electromagnetic Wave Resistivity III ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron ED C Las 21804 Induction/Resistivity 217 7221 Open 8/14/2012 BAT Bi-Modal Acoustic DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron+Graphics tiff,cgm,emf, lis,pdf,tiff ED C Las 22764 Report: Final Well RE 0 7221 Open 1/18/2013 Surface Data Logging End of Well Report LAS TIFF PDF EMF Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report (' Directional/Inclination Data a Mud Logs, Image Files,Digital Data 6/NA Core Chips YdIP, III Production Test Information Y '�Me Mechanical Integrity Test Information YOA Y/f Composite Logs, Image, Data Files G - Core Photographs Y/a Geologic Markers/Tops G Daily Operations Summary a Cuttings Samples Y/'C% Laboratory Analyses Y6),, COMPLIANCE HISTORY Completion Date: 7/7/2012 Release Date: 4/12/2012 Description Date Comments AOGCC Page 2 of 3 Wednesday,October 09,2013 DATA SUBMITTAL COMPLIANCE REPORT 10/9/2013 Permit to Drill 2120410 Well Name/No. BELUGA RIV UNIT 242-04 Operator CONOCOPHILLIPS ALASKA INC API No. 50-283-20164-00-00 MD 7221 TVD 6650 Completion Date 7/7/2012 Completion Status 1-GAS Current Status 1-GAS UIC No Comments: Compliance Reviewed By: Date: o3t-x-ts AOGCC Page 3 of 3 Wednesday,October 09,2013 RECEIVED Conoco Phillips JAN 1 12013 TRANSMITTAL AOGCC CONFIDENTIAL DATA FROM: Sandra D. Lemke,ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. State of Alaska-AOGCC P.O. Box 100360 333 W.7th Ave, Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: BRU 242-04 AOGCC permit: 212-041-0 DATE: 01/08/2013 Transmitted: Beluga River Unit, Alaska BRU 242-04 Z?(.0 t J CD and hardcopy report 2 ✓ End of Well report, Mud logging report, Halliburton; BRU 242-04(502832016400)June 26,2012 General information,daily summary, morning reports, bit data, mud report,formation tops, survey report, days vs.depth Final logs, Halliburton Log Viewer, EMF Log Viewer, EOW report in.pdf,ADI backsup Hardcopy log prints 2"MD Engineering Lore- 2"Formation Evaluation Log 5"formation Evaluation Log., 2"TVD Formation Evaluation Log Please promptly Sign,Scan and Return electronically to Sandra.D.LemkenaConacophiihpscom CC: BRU 242-0 transmittal folder, production well files, eSearch Receipt: Date: 1( ‘9„.___ ?Z 13 10111111111111111 104 GIS-Technical Data Management I ConocoPhiIlips I Anchorage,Alaska I Ph: 907.255 6947 d — 6 cf( • 2772 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 24, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Circumferential Acoustic Scanning Tool/Cement Bond Log/Correlation: BRU 242-04 Run Date: 07/01/2012 - 07/05/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 242-04 Digital Data in LAS/DLIS format, Digital Log Image files 1 CD Rom 50-283-20164-00 Circumferential Acoustic Scanning Tool (Field Print) 1 Color Log 50-283-20164-00 Cement Bond Log(Field Print) 1 Color Log 50-283-20164-00 Advanced Cement Evaluation (ACE Processed Log) 1 Color Log 50-283-20164-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 2q l2- Signed: / 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas 0 ' SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development iv Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: f 0 krtl Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: �6��Z2Q`2012 212-041 /312-238 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 June 1,2012 50-283-20164-00. 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 201'FNL,368'FEL,Sec.4,T12N,R1OW,SM . June 16,2012 BRU 242-04 • Top of Productive Horizon: 8.KB(ft above MSL): 110.6'RKB 15.Field/Pool(s): 2060'FNL,742'FEL,Sec.4,T12N,R1OW,SM GL(ft above MSL): 92'AMSL Beluga River Field • Total Depth: 9.Plug Back Depth(MD+ND): 2329'FNL,780'FEL,Sec.4,T12N, R1OW,SM 7200'MD/6628'ND ° Beluga River Undefined Gas Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-315291 Y- 2619715 Zone-4 7221'MD/6650'ND° A-029656 ° TPI: x-314891 y- 2617863 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-314848 y- 2617595 Zone-4 539'MD/539'ND n/a 18.Directional Survey: Yes Q . No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) not applicable 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Windo LMD/TVD GR/Res,CBL not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 20" 154.19# X-65 18.5 110' 18.5' 110' na pre-driven 9.625" 40# L-80 17.5 3335' 17.5' 2828' 12.25" 324 bbls Class G 7" 26# L-80 16.5 7209' 16.5' 6638' 8.75" 157 bbls Class G 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/ND) 4.5"x 3.5" 5501'x 6445' 5517'MD/4971'ND,5685'MD/5136'ND, 5620'-5634'MD 5072'-5086'ND 5 spf . - pkrs=5864'MD/5312'ND,6235'MD/5678'ND,6383'MD/5824'ND 5750'-5766'MD 5200'-5216' ND 5 spf .�uR1rLn-tly 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 6190'-6206'MD 5634'-5650'ND 5 spf t`. - q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 6260'-6280'MD 5703'-5723'ND 5 spf � . a 5620'-5634' 105K#20/40 RCC 6300'-6305'MD 5742'-5747'ND 5 spf ��• � . 5750'5766' r'~/101K#20!40 RCC 7100'-7111'MD 6530'-6541'ND 5 spf 6190'-6206' < 88K#20/40 RCC frac @ 7100'-7111'with 100K#20/40 RCC 6260'-6280'and 6300'-6305' 100K#20/40 RCC 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) shut-in Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> - Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No El • Sidewall Cores Acquired? Yes ❑ No El, If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 2QJI E5C # OCT 0 2 ElvED ?OI? NONE RBDMS OCT 0 2 2012 AOGCC Form 10-407 Revised 12/2009 t CONTINUED ON REVERSE Submit original only G MIL 28. GEOLOGIC MARKERS(List all formations andSrs encountered): 29. IIIII FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 111 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom not applicable not applicable needed,and submit detailed test information per 20 MC 25.071. Beluga G 5370' 4826' Beluga H 5773' 5223' Beluga I 6530' 5969' N/A Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey ;MS 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4297 Printed Name A 4 Alvord Title: Drilling Manager �';ry��tL Signature Phone 265-6120 Date 0 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 1a: 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 TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: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 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 • BRU 242-04 • Grassroots Well As Built Completion Schematic 9-1-12 20',.75',API 5L GRB, Full . i % Upper Completion MD TVD Grvd, R3 Driven to Refusal Below Pad G ade 1- 8-0 ) 110' 1) BP6i SCSSSV w/'/a'SS control line 539 539 1 2) Chemical In). Sub w/DCV&3/8"SS control line 5,359 4,815 Cannon Coupling Protectors Il 3) 4-'/2"Camco KBG-2 GLM w/DCK-2(2,500 psi) 5,409 4,865 Tubing clamp protector,over i I coupling type,w/channel for(left to I' 4)XN Profile,3.725"ID 5,436 4,891 right):0.375"bare line,0.250"bare ' line. Low carbon steel.25.25"long. � II 5) 80-40 GBH-22 Seal Assembly 5,477 4,931' I jI y Lower Completion TOC+/-3147'MD/2876'TVD f ! 6) Liner Setting Sleeve, RS Nipple,4"Seal Bore 5,472 4,927 500'above the top Sterling % ' i1 ---/ 7) 3 1/2"x 7"Premier Production Packer 5,517 4,971 Surface Casing: 9-5/8",40#, L-80, BTC I Set @ 3335'MD/2831'TVD 8) X Profile,2.813 ID 5,537 4,991 9) 3 1/2"Halliburton Frac Door w /w/2.75"Bore 5,577 5,030 10) 3 1/2"Carbide Blast Rings 5,615 5,067 I 11) 3 1/2"Selecta Flow Screen w/2.75"X profile 5,654 5,106 12) 3 1/2"x 7"Premier Isolation Packer 5,685 5,136 Production Tubing: 2 4'h",12.6#, L-80, IBT-M to 13) 3 1/2"Halliburton Frac Door w/2.75"Bore 5,736 5,186 5,459'MD/4,914'TVD GL 3 3'/2',9.3#L-80, IBT-M to ----- 0)-4'15 14) 3 1/2"Carbide Blast Rings 5,745 5,195 5,509"MD,4,963'TVD - - 4 5 61mr 5 7 15) 3 1/2"Selecta Flow Screen w/2.75"X profile 5,815 5,264 Ei we .N, 8-- 9 _._ 16) 3 1/2"x 7"Premier Isolation Packer 5,864 5,312 G Sand Peforations(5 spf) .- 2..-. - -•_ @ 5,620'-5,634'(14') (e._ '- 10 - I�� -,•Frac'd w/105 K lbs 20/40 RCC - 11 -_- 17) 3 1/2"Halliburton Frac Door w/w/2.75"Bore 6,142 5,587 12 ■ ■ 13 - 18) 3 1/2"Carbide Blast Rings 6,185 5,629 G Sand Peforations(5 spf) - _:_ - _ @ 5,750'- 5,766'(16') '' 14 -_ _._--.�-� 19) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,219 5,663 Frac'd w/101 K lbs 20/40 RCC --17 15 16 20) 3 1/2"x 7"Premier Isolation Packer 6,235 5,678 H Sand Peforations(5 spf) -.-:.-_-:-T: 17 _ @ 6,190' 6,206'(16') \(.- '- 18 �_ ---1 21) 3 1/2"Halliburton Frac Door w/w/2.75"Bore 6,251 5,694 Frac'd w/88 K lbs 20/40 RCC _ - 20 22) 3 1/2"Carbide Blast Rings 6,257 5,700 H Sand Peforations(5 spf) - - - ,_ 21 - _- @ 6,260'-6,280'(20') / c•- .� 22- L' : ) 23) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,327 5,769 6,300'-6,305'(5') =•= 23 24 -7..---1- - Frac'd w/100K lbs 20/40RCC • am 24) 3 1/2"x 7"Premier Isolation Packer 6,383 5,824 I Sand Peforations(5 spf) _ _ _•_ 25) 1"SO Ball Seat w/Wireline Entry Guide 6,444 5,884 @ 7,100'-7,111'(11') - -: 25 - \ Frac'd w/100 K lbs 20/40 RCC• �_ Production Casing: 7",26.00#, L-80, BTC-Mod Set @ 7200' MD/6685'TVD • • 1 [ q - ,,I i 1 r ConocoPhillips(Alaska) Inc. Beluga River Beluga River BRU 242-04 rt 1 "" Sperry Drilling y� 3 Definitive Survey Report q. 4 06 July, 2012 �u 4 m c- I q II ma i HAL.LWBURTON i Sperry Drilling • • ConocoPhillips (Alaska) Inc. Definitive Survey Report mr s m � °'aninne r fmr� Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Project Beluga River Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well BRU 242-04 Well Position +N/-S 0.00 ft Northing: 2,619,715.42 ft Latitude: 61°9'58.660 N +El-W 0.00 ft Easting: 315,291.27 ft Longitude: 151°2'45.874 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.14ft Wellbore BRU 242-04 Magnetics Mo �lame - Declination g ie �fil1' �i�14P Fre�vE,�tre II��6� (0) ,11 hi 4i" ) YAM BGGM2011 6/17/2012 17.74 74.02 55,688 ;__ �,.^_ I .,,. -, - Ju =- IIII��IN�'d&L3Nk9�a •'111111 t Design BRU 242-04 - i -- -_ .. i n� ° - r ii r ,. -. .�., •,�,. imi r ii� ry ii ,r i �+u iuu i lull_ -�"miae� Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: �' pfhfroth T $= q!Ih +N/-S liar °hl�l �l" "� _ ct 4�If�� Ei�l (ft) tft) ��1�� `(ft) �;��I,� �q i�=r = �� O 18.50 0.00 0.00 190.88 Survey Program Date 7/6/2012 From To �' , �i Id�,� , (ft) (ft) Survey(Wellbore) Tool Name Description t dhi--., tihtey Date 148.21 3,254.78 BRU 242-04(BRU 242-04) MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C7/6/2012 12:0C 3,352.40 7,175.95 BRU 242-04(BRU 242-04) MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C7/6/2012 12:OC Survey Map Map MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting O Section (ft) (1 (°) (ft) (ft); (ft) (ft) (ft) (ft) (01100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -92.14 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 UNDEFINED 148.21 0.55 340.24 148.21 37.57 0.59 -0.21 2,619,716.01 315,291.07 0.42 -0.54 MWD+SCC+SAG(1) 185.05 0.39 327.89 185.05 74.41 0.86 -0.34 2,619,716.28 315,290.95 0.51 -0.78 MWD+SCC+SAG(1) 244.05 0.28 329.34 244.05 133.41 1.15 -0.52 2,619,716.58 315,290.77 0.19 -1.03 MWD+SCC+SAG(1) 309.29 0.14 260.19 309.29 198.65 1.28 -0.68 2,619,716.70 315,290.62 0.41 -1.13 MWD+SCC+SAG(1) 369.72 0.99 225.52 369.71 259.07 0.90 -1.12 2,619,716.33 315,290.17 1.45 -0.67 MWD+SCC+SAG(1) 429.41 2.47 214.78 429.37 318.73 -0.52 -2.22 2,619,714.93 315,289.04 2.53 0.93 MWD+SCC+SAG(1) 486.29 3.52 205.16 486.18 375.54 -3.11 -3.67 2,619,712.37 315,287.56 2.04 3.74 MWD+SCC+SAG(1) 548.08 4.37 203.40 547.82 437.18 -6.98 -5.41 2,619,708.52 315,285.76 1.39 7.88 MWD+SCC+SAG(1) 615.28 5.54 205.30 614.77 504.13 -12.27 -7.81 2,619,703.28 315,283.27 1.76 13.52 MWD+SCC+SAG(1) 676.29 6.48 206.32 675.44 564.80 -18.02 -10.60 2,619,697.57 315,280.39 1.55 19.69 MWD+SCC+SAG(1) 741.28 7.69 202.75 739.93 629.29 -25.31 -13.90 2,619,690.33 315,276.97 1.98 27.48 MWD+SCC+SAG(1) 804.16 9.11 197.97 802.14 691.50 -33.93 -17.07 2,619,681.77 315,273.67 2.51 36.54 MWD+SCC+SAG(1) 7/6/2012 10:34:49AM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: 'CPAI EDM Production ) Map Map Vertical MD w Ine 147 1/D VDSS . Ni +E/-W Northing Easting DLS Section (ft) t V eft) (ft) Tilio4, (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 867.08 12.55 196.10 863.93 753.29 -45.24 -20.50 2,619,670.52 315,270.05 5.49 48.29 MWD+SCC+SAG(1) 898.93 14.64 197.72 894.88 784.24 -52.40 -22.68 2,619,663.39 315,267.75 6.67 55.74 MWD+SCC+SAG(1) 926.93 16.09 197.63 921.88 811.24 -59.47 -24.94 2,619,656.36 315,265.39 5.18 63.10 MWD+SCC+SAG(1) 962.10 17.36 199.18 955.56 844.92 -69.07 -28.14 2,619,646.81 315,262.04 3.83 73.14 MWD+SCC+SAG(1) 990.49 18.57 198.26 982.57 871.93 -77.36 -30.94 2,619,638.57 315,259.10 4.38 81.81 MWD+SCC+SAG(1) 1,053.84 20.14 196.89 1,042.34 931.70 -97.38 -37.27 2,619,618.65 315,252.45 2.58 102.66 MWD+SCC+SAG(1) 1,116.87 22.03 195.58 1,101.14 990.50 -119.15 -43.60 2,619,596.99 315,245.77 3.09 125.24 MWD+SCC+SAG(1) 1,178.50 24.75 194.16 1,157.71 1,047.07 -142.80 -49.86 2,619,573.45 315,239.13 4.51 149.64 MWD+SCC+SAG(1) 1,243.17 28.78 192.87 1,215.44 1,104.80 -171.11 -56.65 2,619,545.24 315,231.90 6.30 178.73 MWD+SCC+SAG(1) 1,279.06 30.84 192.44 1,246.57 1,135.93 -188.52 -60.55 2,619,527.90 315,227.72 5.77 196.56 MWD+SCC+SAG(1) 1,305.36 31.68 192.52 1,269.06 1,158.42 -201.84 -63.50 2,619,514.63 315,224.55 3.20 210.20 MWD+SCC+SAG(1) 1,371.15 32.31 192.74 1,324.85 1,214.21 -235.86 -71.12 2,619,480.74 315,216.39 0.97 245.04 MWD+SCC+SAG(1) 1,433.89 34.65 193.02 1,377.18 1,266.54 -269.59 -78.84 2,619,447.13 315,208.13 3.74 279.63 MWD+SCC+SAG(1) 1,495.96 35.89 192.60 1,427.85 1,317.21 -304.54 -86.79 2,619,412.32 315,199.63 2.04 315.45 MWD+SCC+SAG(1) 1,558.62 37.52 192.32 1,478.09 1,367.45 -341.11 -94.86 2,619,375.89 315,190.97 2.62 352.89 MWD+SCC+SAG(1) 1,621.24 41.74 190.68 1,526.31 1,415.67 -380.24 -102.80 2,619,336.89 315,182.41 6.94 392.81 MWD+SCC+SAG(1) 1,653.10 44.26 189.55 1,549.61 1,438.97 -401.63 -106.61 2,619,315.56 315,178.26 8.27 414.54 MWD+SCC+SAG(1) 1,684.76 46.24 188.08 1,571.90 1,461.26 -423.85 -110.05 2,619,293.41 315,174.46 7.07 437.01 MWD+SCC+SAG(1) 1,718.58 46.87 189.29 1,595.15 1,484.51 -448.12 -113.76 2,619,269.20 315,170.37 3.20 461.54 MWD+SCC+SAG(1) 1,747.34 47.30 190.03 1,614.74 1,504.10 -468.89 -117.29 2,619,248.50 315,166.50 2.41 482.60 MWD+SCC+SAG(1) 1,810.50 48.65 190.54 1,657.02 1,546.38 -515.05 -125.67 2,619,202.48 315,157.39 2.22 529.51 MWD+SCC+SAG(1) 1,869.68 51.22 190.73 1,695.11 1,584.47 -559.56 -134.03 2,619,158.11 315,148.32 4.35 574.80 MWD+SCC+SAG(1) 1,936.77 52.31 191.13 1,736.63 1,625.99 -611.30 -144.03 2,619,106.54 315,137.50 1.69 627.50 MWD+SCC+SAG(1) 1,995.43 51.48 191.09 1,772.83 1,662.19 -656.59 -152.92 2,619,061.39 315,127.88 1.42 673.65 MWD+SCC+SAG(1) 2,059.55 50.23 191.10 1,813.30 1,702.66 -705.39 -162.49 2,619,012.76 315,117.53 1.95 723.38 MWD+SCC+SAG(1) 2,121.88 49.37 190.17 1,853.53 1,742.89 -752.18 -171.28 2,618,966.12 315,108.00 1.79 770.99 MWD+SCC+SAG(1) 2,185.18 48.61 191.25 1,895.07 1,784.43 -799.11 -180.15 2,618,919.34 315,098.37 1.76 818.75 MWD+S0C+SAG(1) 2,248.43 47.96 190.67 1,937.16 1,826.52 -845.46 -189.13 2,618,873.14 315,088.66 1.23 865.96 MWD+SCC+SAG(1) 2,310.69 47.27 190.13 1,979.13 1,868.49 -890.69 -197.43 2,618,828.05 315,079.63 1.28 911.95 MWD+SCC+SAG(1) 2,375.67 45.68 189.16 2,023.88 1,913.24 -937.14 -205.33 2,618,781.74 315,070.99 2.68 959.05 MWD+SCC+SAG(1) 2,438.98 43.64 188.39 2,068.91 1,958.27 -981.11 -212.12 2,618,737.88 315,063.50 3.33 1,003.52 MWD+SCC+SAG(1) 2,501.78 42.08 188.73 2,114.94 2,004.30 -1,023.35 -218.48 2,618,695.75 315,056.47 2.51 1,046.20 MWD+SCC+SAG(1) 2,563.56 39.80 189.00 2,161.61 2,050.97 -1,063.35 -224.72 2,618,655.86 315,049.59 3.70 1,086.65 MWD+SCC+SAG(1) 2,627.46 37.10 189.53 2,211.65 2,101.01 -1,102.56 -231.11 2,618,616.76 315,042.58 4.26 1,126.37 MWD+SCC+SAG(1) 2,690.89 35.80 189.16 2,262.67 2,152.03 -1,139.75 -237.23 2,618,579.68 315,035.86 2.08 1,164.04 MWD+SCC+SAG(1) 2,751.40 34.54 188.77 2,312.13 2,201.49 -1,174.18 -242.66 2,618,545.34 315,029.88 2.12 1,198.87 MWD+SCC+SAG(1) 2,815.13 33.29 188.68 2,365.01 2,254.37 -1,209.32 -248.06 2,618,510.29 315,023.92 1.96 1,234.41 MWD+SCC+SAG(1) 2,877.83 32.04 190.06 2,417.80 2,307.16 -1,242.71 -253.56 2,618,477.00 315,017.89 2.32 1,268.23 MWD+SCC+SAG(1) 2,941.54 30.41 190.45 2,472.28 2,361.64 -1,275.21 -259.44 2,618,444.60 315,011.49 2.58 1,301.26 MWD+SCC+SAG(1) 3,005.33 28.83 189.59 2,527.73 2,417.09 -1,306.25 -264.93 2,618,413.65 315,005.51 2.56 1,332.78 MWD+SCC+SAG(1) 7/6/2012 10:34:49AM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Survey ,, mrwr, Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (01100') (ft) Survey Tool Name 3,068.83 27.01 189.36 2,583.84 2,473.20 -1,335.58 -269.82 2,618,384.41 315,000.14 2.87 1,362.50 MWD+SCC+SAG(1) 3,129.56 25.44 189.95 2,638.31 2,527.67 -1,362.04 -274.32 2,618,358.03 314,995.22 2.62 1,389.33 MWD+SCC+SAG(1) 3,191.47 23.51 190.13 2,694.66 2,584.02 -1,387.29 -278.79 2,618,332.85 314,990.35 3.12 1,414.98 MWD+SCC+SAG(1) 3,254.78 21.35 189.97 2,753.17 2,642.53 -1,411.07 -283.01 2,618,309.14 314,985.75 3.41 1,439.13 MWD+SCC+SAG(1) 3,352.40 18.54 190.95 2,844.93 2,734.29 -1,443.82 -289.03 2,618,276.49 314,979.20 2.90 1,472.42 MWD+SCC+SAG(2) 3,400.42 17.02 190.29 2,890.66 2,780.02 -1,458.23 -291.74 2,618,262.13 314,976.27 3.19 1,487.09 MWD+SCC+SAG(2) 3,463.87 13.80 187.04 2,951.82 2,841.18 -1,474.88 -294.32 2,618,245.52 314,973.42 5,25 1,503.93 MWD+SCC+SAG(2) 3,498.71 12.72 185.50 2,985.73 2,875.09 -1,482.82 -295.20 2,618,237.59 314,972.41 3.26 1,511.89 MWD+SCC+SAG(2) 3,525.12 12.57 185.74 3,011.50 2,900.86 -1,488.58 -295.77 2,618,231.85 314,971.75 0.60 1,517.65 MWD+SCC+SAG(2) 3,589.05 12.49 190.22 3,073.91 2,963.27 -1,502.30 -297.69 2,618,218.16 314,969.61 1.53 1,531.49 MWD+SCC+SAG(2) 3,652.03 12.72 190.70 3,135.37 3,024.73 -1,515.82 -300.19 2,618,204.69 314,966.90 0.40 1,545.23 MWD+SCC+SAG(2) 3,715.94 11.18 188.92 3,197.89 3,087.25 -1,528.85 -302.45 2,618,191.69 314,964.43 2.48 1,558.46 MWD+SCC+SAG(2) 3,778.73 10.68 192.05 3,259.54 3,148.90 -1,540.56 -304.61 2,618,180.02 314,962.08 1.24 1,570.36 MWD+SCC+SAG(2) 3,842.33 10.90 192.18 3,322.02 3,211.38 -1,552.20 -307.11 2,618,168.42 314,959.40 0.35 1,582.27 MWD+SCC+SAG(2) 3,902.78 10.78 192.10 3,381.39 3,270.75 -1,563.31 -309.50 2,618,157.35 314,956.83 0.20 1,593.63 MWD+SCC+SAG(2) 3,966.83 10.02 192.22 3,444.39 3,333.75 -1,574.62 -311.94 2,618,146.09 314,954.21 1.19 1,605.19 MWD+SCC+SAG(2) 4,030.43 10.17 191.99 3,507.00 3,396.36 -1,585.52 -314.27 2,618,135.23 314,951.70 0.24 1,616.34 MWD+SCC+SAG(2) 4,090.95 10.33 191.83 3,566.56 3,455.92 -1,596.05 -316.50 2,618,124.73 314,949.31 0.27 1,627.10 MWD+SCC+SAG(2) 4,154.77 10.29 191.10 3,629.35 3,518.71 -1,607.25 -318.77 2,618,113.57 314,946.86 0.21 1,638.53 MWD+SCC+SAG(2) 4,216.22 10.11 192.57 3,689.82 3,579.18 -1,617.90 -321.00 2,618,102.96 314,944.46 0.52 1,649.41 MWD+SCC+SAG(2) 4,281.50 10.03 190.05 3,754.10 3,643.46 -1,629.09 -323.24 2,618,091.81 314,942.04 0.69 1,660.82 MWD+SCC+SAG(2) 4,344.50 10.04 190.00 3,816.14 3,705.50\ -1,639.90 -325.15 2,618,081.03 314,939.96 0.02 1,671.79 MWD+SCC+SAG(2) 4,408.55 9.79 189.42 3,879.23 3,768.59 -1,650.77 -327.01 2,618,070.19 314,937.93 0.42 1,682.82 MWD+SCC+SAG(2) 4,471.09 10.22 190.67 3,940.82 3,830.18 -1,661.47 -328.91 2,618,059.52 314,935.86 0.77 1,693.68 MWD+SCC+SAG(2) 4,535.21 10.40 191.37 4,003.90 3,893.26 -1,672.73 -331.10 2,618,048.30 314,933.48 0.34 1,705.16 MWD+SCC+SAG(2) 4,597.75 10.15 191.15 4,065.44 3,954.80 -1,683.67 -333.28 2,618,037.39 314,931.13 0.40 1,716.31 MWD+SCC+SAG(2) 4,660.16 10.29 191.41 4,126.86 4,016.22 -1,694.53 -335.44 2,618,026.57 314,928.79 0.24 1,727.39 MWD+SCC+SAG(2) 4,723.88 10.33 191.43 4,189.55 4,078.91 -1,705.71 -337.70 2,618,015.43 314,926.35 0.06 1,738.79 MWD+SCC+SAG(2) 4,787.12 10.25 192.05 4,251.77 4,141.13 -1,716.77 -340.00 2,618,004.41 314,923.88 0.22 1,750.09 MWD+SCC+SAG(2) 4,848.17 10.01 191.12 4,311.87 4,201.23 -1,727.29 -342.16 2,617,993.93 314,921.55 0.48 1,760.82 MWD+SCC+SAG(2) 4,910.58 9.92 190.24 4,373.34 4,262.70 -1,737.90 -344.16 2,617,983.35 314,919.38 0.28 1,771.62 MWD+SCC+SAG(2) 4,973.22 9.82 189.30 4,435.05 4,324.41 -1,748.48 -345.98 2,617,972.80 314,917.39 0.30 1,782.36 MWD+SCC+SAG(2) 5,037.12 10.07 192.15 4,497.99 4,387.35 -1,759.32 -348.04 2,617,962.00 314,915.16 0.86 1,793.39 MWD+SCC+SAG(2) 5,101.01 10.24 193.48 4,560.88 4,450.24 -1,770.30 -350.54 2,617,951.06 314,912.49 0.45 1,804.65 MWD+SCC+SAG(2) 5,162.48 10.35 192.34 4,621.36 4,510.72 -1,781.01 -352.99 2,617,940.39 314,909.86 0.38 1,815.62 MWD+SCC+SAG(2) 5,224.97 10.32 192.41 4,682.84 4,572.20 -1,791.96 -355.39 2,617,929.48 314,907.29 0.05 1,826.83 MWD+SCC+SAG(2) 5,286.63 10.15 191.97 4,743.52 4,632.88 -1,802.67 -357.71 2,617,918.81 314,904.80 0.30 1,837.78 MWD+SCC+SAG(2) 5,350.49 10.03 193.36 4,806.39 4,695.75 -1,813.58 -360.16 2,617,907.94 314,902.18 0.43 1,848.97 MWD+SCC+SAG(2) 5,413.09 9.96 193.38 4,868.04 4,757.40 -1,824.16 -362.67 2,617,897.41 314,899.50 0.11 1,859.82 MWD+SCC+SAG(2) 5,476.24 9.73 193.47 4,930.26 4,819.62 -1,834.66 -365.18 2,617,886.95 314,896.82 0.37 1,870.61 MWD+SCC+SAG(2) 7/6/2012 10:34.:49AM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River ND Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference; 41, Rig:242-04 @ 110.64ft(Artie Fox) Well: BRU 242-04 Forth erence'� ' True Wellbore: BRU 242-04 Surv` `Calcuiati Meth : ~ Minimum Curvature Design: BRU 242-04 3atabase �� CPAI EDM Production Survey = r ilinti� ilG}k a � i 3i��) ry GIT Ili , � i� r �� '■ t V Iiic"el,'ki4 �nQ MD Inc Azi ND TVDSS +N/- }E/-W No hitt stln DLS Section (ft) (°1 (0) (ft) (ft) I (ft) (ft) ft i� '.(ft} �i.�:iii(01100), (ft) Survey Tool Name 5,539.38 9.57 193.91 4,992.51 4,881.87 -1,844.94 367.68 2,617,876.70 314,894.15 0.28 1,881.18 MWD+SCC+SAG(2) 5,602.35 10.08 191.87 5,054.55 4,943.91 -1,855.42 -370.08 2,617,866.27 314,891.59 0.98 1,891.92 MWD+SCC+SAG(2) 5,665.31 10.15 190.15 5,116.53 5,005.89 -1,866.27 -372.19 2,617,855.45 314,889.31 0.49 1,902.97 MWD+SCC+SAG(2) 5,728.58 10.02 190.04 5,178.83 5,068.19 -1,877.18 -374.13 2,617,844.58 314,887.19 0.21 1,914.05 MWD+SCC+SAG(2) 5,791.64 9.96 189.45 5,240.93 5,130.29 -1,887.96 -375.98 2,617,833.83 314,885.17 0.19 1,924.99 MWD+SCC+SAG(2) 5,853.67 9.88 189.15 5,302.03 5,191.39 -1,898.50 -377.71 2,617,823.31 314,883.27 0.15 1,935.67 MWD+SCC+SAG(2) 5,915.71 9.84 189.70 5,363.16 5,252.52 -1,908.98 -379.45 2,617,812.86 314,881.37 0.16 1,946.29 MWD+SCC+SAG(2) 5,980.28 9.76 189.45 5,426.79 5,316.15 -1,919.82 -381.27 2,617,802.06 314,879.37 0.14 1,957.28 MWD+SCC+SAG(2) 6,042.35 9.45 187.97 5,487.98 5,377.34 -1,930.06 -382.85 2,617,791.85 314,877.63 0.64 1,967.63 MWD+SCC+SAG(2) 6,105.54 9.16 187.79 5,550.34 5,439.70 -1,940.18 -384.25 2,617,781.75 314,876.07 0.46 1,977.83 MWD+SCC+SAG(2) 6,167.75 9.02 188.91 5,611.77 5,501.13 -1,949.90 -385.67 2,617,772.05 314,874.49 0.36 1,987.65 MWD+SCC+SAG(2) 6,231.97 9.55 190.39 5,675.15 5,564.51 -1,960.11 387.41 2,617,761.87 314,872.58 0.91 1,998.01 MWD+SCC+SAG(2) 6,293.76 9.88 189.95 5,736.05 5,625.41 -1,970.38 -389.25 2,617,751.64 314,870.58 0.55 2,008.43 MWD+SCC+SAG(2) 6,356.77 10.37 189.96 5,798.08 5,687.44 -1,981.29 -391.17 2,617,740.76 314,868.49 0.78 2,019.51 MWD+SCC+SAG(2) 6,419.72 10.38 189.51 5,860.00 5,749.36 -1,992.46 -393.09 2,617,729.62 314,866.40 0.13 2,030.84 MWD+SCC+SAG(2) 6,482.50 10.37 189.45 5,921.76 5,811.12 -2,003.61 394.95 2,617,718.50 314,864.36 0.02 2,042.14 MWD+SCC+SAG(2) 6,545.82 10.18 189.21 5,984.06 5,873.42 -2,014.76 -396.78 2,617,707.39 314,862.35 0.31 2,053.43 MWD+SCC+SAG(2) 6,608.40 9.93 188.86 6,045.68 5,935.04 2,025.55 398.50 2,617,696.63 314,860.46 0.41 2,064.36 MWD+SCC+SAG(2) 6,672.94 10.02 188.63 6,109.24 5,998.60 2,036.60 400.19 2,617,685.61 314,858.58 0.15 2,075.53 MWD+SCC+SAG(2) 6,734.96 9.85 187.08 6,170.34 6,059.70 2,047.20 -401.66 2,617,675.03 314,856.95 0.51 2,086.21 MWD+SCC+SAG(2) 6,796.88 9.77 186.52 6,231.35 6,120.71 -2,057.67 402.91 2,617,664.58 314,855.53 0.20 2,096.73 MWD+SCC+SAG(2) 6,860.77 9.76 186.88 6,294.31 6,183.67 -2,068.43 404.17 2,617,653.84 314,854.10 0.10 2,107.54 MWD+SCC+SAG(2) 6,923.80 9.81 186.35 6,356.43 6,245.79 2,079.07 405.41 2,617,643.22 314,852.69 0.16 2,118.22 MWD+SCC+SAG(2) 6,987.55 9.79 186.26 6,419.25 6,308.61 -2,089.86 406.60 2,617,632.46 314,851.33 0.04 2,129.04 MWD+SCC+SAG(2) 7,049.72 9.43 184.50 6,480.54 6,369.90 2,100.19 407.57 2,617,622.14 314,850.19 0.75 2,139.37 MWD+SCC+SAG(2) 7,113.24 9.28 182.87 6,543.22 6,432.58 -2,110.49 -408.24 2,617,611.85 314,849.36 0.48 2,149.61 MWD+SCC+SAG(2) 7,175.95 9.06 182.67 6,605.13 6,494.49 2,120.48 -408.72 2,617,601.88 314,848.72 0.35 2,159.51 MWD+SCC+SAG(2) 7,221.00 9.06 182.67 6,649.62 6,538.98 2,127.56 409.05 2,617,594.80 314,848.27 0.00 2,166.53 PROJECTED to TD 716/2012 10:34:49AM Page 5 COMPASS 2003.16 Build 69 • • Conoc©Phillips Time Log & Summary We/Iview Web Reporting Report Well Name: BRU 242-04 Rig Name: Job Type: OTHER Rig Accept: Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/21/2012 24 y hr Summar Recieve barge,w/water tank,sub base and loader, off load barge, haul water tank and sub to location, hang stairs on side of sub base, install roof cap on sub, hang knee braces on sub and clean sub base. 00:00 12:00 12.00 0 MIRU MOVE MOB P Cont. moblizing rig,clean and organize welding shop,service loader, haul water tank from landing to location, 12:00 14:00 2.00 MIRU MOVE MOB P Move sub base and spot on location. 14:00 18:00 4.00 MIRU MOVE MOB P Hang knee braces on upper sub, install stair ways, install roof cap on sub 18:00 00:00 6.00 MIRU MOVE MOB P Hang knee braces for walk ways and clean sub base 05/22/2012 Clean rig units.Offload barge. Set upper section, raise roof on shop.Sort windwalls, hang shop doors.,set ODS corner wind walls on sub.Set up supports for dig house.Chain diverter stack to sub.Continue cleaning rig shoq and units. 00:00 12:00 12.00 MIRU MOVE MOB P Held Pre-tour meeting.Clean rig units.Offload barge,set upper sub section, raise roof on shop.Set mechanic shop. Unload windwall form tubs. 12:00 00:00 12.00 MIRU MOVE MOB P Held Pre-tour meeting.Conitnue sort windwalls, hang shop doors. Install ODS corner wind wall on sub base. Set up supports for doghouse.Chain &secure diverter stack to sub. Continue cleaning shop and rig units. MI begin sorting and setting equipment at BRWD. 05/23/2012 Continue rigging up on location, haul pits to location. PJSM, Install shaker box and shakers onto pits. PJSM, hang windwalls on sub base. install hand rails on pits, install wind walls around shakers, unload pipe tub with misc.equip for rig and pits, PJSM, pressure wash rig units. 00:00 00:30 0.50 MIRU MOVE SFTY P Held Pre-tour safety meeting. 00:30 12:00 11.50 MIRU MOVE MOB P Haul pits to location, PJSM and raise roof sections on pits 12:00 12:30 0.50 MIRU MOVE MOB P Held Pre-tour safety meeting. 12:30 00:00 11.50 MIRU MOVE MOB P PJSM Install shaker on pits, install hand rails on pit mobule, PJSM,install wind walls around shakers, unload tub of misc. rig parts, pressure wash rig units 05/24/2012 Pre tour safety meeting,continue installing wind walls and hand rails on pits,continue cleaning rig modules, Pre tour safety meeting, prepare location for incoming rig modules,off load big barge at beluga landing, haul modules and derrick to location.set support buildings,unitsinstalll derrick, continue rig up at BRWD. Page 1 of 6 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code ` Subcode T Comment 00:00 00:30 0.50 MIRU MOVE SFTY P Pretour safety meeting 00:30 12:00 11.50 MIRU MOVE MOB P Continue installing wind walls and hand rails on pits,continue clean rig modules. Prepare location for incoming rig modules.Off load big barge at beluga landing. Haul modules and derrick to location.Set pits. Continiue rig up at BRWD. 12:00 12:30 0.50 MIRU MOVE MOB P Pretour safety meeting. 12:30 00:00 11.50 MIRU MOVE MOB P Set rig modules with the trucks. Held PJSM discussing derrick lift. Prep derrick and set on the sub with both cranes. Pin it.Continue rig up modules,and attach lines.set pumps 2&3,gen houses 1 &2,water tank, set hole fill pump,set change house, spot dog house on location Continiue rig up at BRWD. 05/25/2012 Continue rigging up,hook up service lines,set top drive hyd unit, install landing and hand rails,set site control house,continue rigging up. 00:00 00:30 0.50 MIRU MOVE SFTY Pre tour safety meeting 00:30 12:00 11.50 MIRU MOVE MOB Continue rigging up rig,continue preping derrick,fab hand rails& install,connect interconnects, hook up fuel,water, air&vac lines,set site control shack. 12:00 12:30 0.50 MIRU MOVE SFTY Pre tour safety meeting 12:30 00:00 11.50 MIRU MOVE MOB PJSM, lay felt&herclits,set mats, set Tesco hyd.unit,set DS wind walls,set rock wash skid, install landing and stairs, install stack on gas buster skid,Start Generator#1, energize rig HPU, rig up drillers consel, install brake handle and linkage, install knee braces for centrifuge. 05/26/2012 Continue rigging up, install braces for centrifuge house,pressure wash derrick board, hook up service lines, start dressing mud pumps w/6"liners, hang derrick board, raise derrick and scope up,set pipe houses,set centrifuge house,pick up top drive, install top drive torque tube. 00:00 00:30 0.50 MIRU MOVE SFTY Pre tour safety meeting 00:30 12:00 11.50 MIRU MOVE MOB Install braces for centrifuge house, pressure wash derrick board, hook up service lines,start dressing mud pumps w/6"liners, install equipment slide,install landing @ door entrances, install derrick board,spot top drive on floor,set centrifuge house, raise derrick and pin. 12:00 12:30 0.50 MIRU MOVE SFTY Pre tour safety meeting Page 2 of 6 Time Logs 9 Date From To Our S. Depth E.Depth Phase Code Subcode T Comment 12:30 00:00 11.50 MIRU MOVE MOB String up drilling line, inspect derrick, install wind walls on rig floor,set roof rafters&roof caps,install roof F/ HPU, install stairs to draw works, auger discharge,scope derrick and pin,pick up top drive&remove cradle, raise cattle schute,energize derrick and pipe shed lights, install lower torque tube for top drive. 05/27/2012 Continue rigging up top drive,transfer water to pits and start checking out circulating system,continue cleaning rig, and workng on welding projects 00:00 00:30 0.50 MIRU MOVE SFTY Pre tour safety meeting 00:30 12:00 11.50 MIRU MOVE RURD Continue installing torque tube for top drive, rig up top drive on torque tube, rig up rig tongs,mud manifold, Install lights on rig floor,continue dressing mud pumps, hang service loop F/top drive @ derrick board, Finish installing diverter line, remove bridle line sheave and guide pin. 12:00 12:30 0.50 MIRU MOVE SFTY Pre tour safety meeting 12:30 00:00 11.50 MIRU Set twin tower and secure to diverter line, install and secure service loop to shaker pit,set koomey unit, rig up mechanic shop, rig up pits and rock washer unit, hook up electrical to pumps 1,2,&3, install elect,&hyd service loop to top drive&energize, install grabber tube on top drive, back out saver sub and change gripper dies,finish securing dog house 05/28/2012 Continue rigging up pits,finish dressing out pumps,finish changing out saver sub,install bails on top drive, hook up germino line and derrick climber,continue with house keeping 00:00 00:30 0.50 MIRU MOVE SFTY Pre tour safety meeting 00:30 06:00 5.50 MIRU MOVE RURD Continue rigging up pits,finish dressing out pumps,finish changing out saver sub, install stabbing guide and secure bolts with tie wire, install bails on top drive, hook up germino line and derrick climber,continue with house keeping 06:00 12:00 6.00 MIRU MOVE RURD Install chain bracing on water tank, Pressure wash pipe shed, inventory pump parts, install centrifuge feed pump,secure bridle Ines in derrick, make up kelly hose 12:00 12:30 0.50 MIRU MOVE SFTY Pre tour safety meeting Page 3 of 6 • Time Logs Date From To Dur` S.Depth E. Depth Phase Code Subcode T `Comment 12:30 00:00 11.50 MIRU MOVE RURD Finish hanging bridle lines,seal rig floor,transfer water to pits,pump thru gun lines,&mix pumps,& bleeders on all pumps,pump thru 4" to shakers, re-plumb hydraulic hoses on top drive and function test, plumb koomey hoses to hydrill and knife valve&function test diverter system, clear rig floor of misc.equipment. 05/29/2012 Function test crown saver,trouble,change out valves in pit system,function test draw works traction motors. 00:00 00:30 0.50 0 0 MIRU MOVE SFTY P Pre tour safety meeting 00:30 06:00 5.50 0 0 MIRU MOVE RURD P Function test crown saver,trouble, change out valves in pit system, function test draw works traction motors.Spot&set break shack, MWD and Mud loggers shacks. 06:00 12:00 6.00 0 0 MIRU MOVE RURD P Modify'bell nipple',organize,and clean all rig complexes. Begin setting up'handi-berm'systems around the rig 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Continue to mobilize the Arctic Fox. Work in pits,install'bell nipple', Install mud lines,secure stack. Clean and organize in preparation for rig acceptance. Modify hand rails for rig floor, install hand rails,Off load all Sperry surface hole BHA components. Install'handi-berm' around rig.Welder installed 2-3" nipples @ 45°angles in conductor. Quadco installing PVT systems,and monitors,and setting up computers. Coms.team on location to begin rigging up. 05/30/2012 Function.test211i"_.2000 lb MSP accumulator,and knife valve. Pressure test mud pumps. Function and test pipe spinners,function and test lay down machine,function and test rotary table,service Doyon 966 loader. Hook up communication lines,fiber optic cable,telephones,set up Totco system. Bring to location spud mud dry products and drums. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Realign'kelly hose'. Pressure test pumps. Electrician trouble shooting electrical problems.(Transformer). Function test the 21%"Annular,and knife valve. 06:00 12:00 6.00 0 0 MIRU MOVE RURD P Continue rig up Sperry Sun MWD Unit. Finish Handy-Berm around rig. Work on installing Totco&COM lines and equipment. Load pipe shed with 110 jnts of 4"DP. Rig up jumper line to camp generator for dog house until replacement transformer arrives. Page 4 of 6 • • Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 12:00 14:00 2.00 0 0 MIRU MOVE SFTY P Held Hand&Finger Safety presentation at Freemans Shop. Discussed Belief process with all Doyon, Peak,MI, MI Swaco, Pollard, Wells Group reps, Halliburton and Sperry Sun. Reps form Production group as well.Crew Change 14:00 18:00 4.00 0 0 MIRU MOVE RURD P Continue load pipe shed with 4"DP, and strap same. Load DS pipe shed with 21 jnts of 5"HWDP,jars and MWD assembly.Continue rig up COM lines,phones and Totco equipment.Continue work on landings for steps. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Work on top drive.Service crown, inspect derrick, Install shock hose between gas buster and choke house.Test rotary table,service Doyon 966 loader and complete acceptance for loader. 05/31/2012 Rig up cellar trash pump. Berm in tertiary containment between rock washer and pits.Clean centrifuge room. Install boiler stack exhaust, install hot well stack exhaust,Test E-stops on pump engines,draw works,top drive, calibrate all torque gauges, make up BHA#1. Bit, bit sub,XO,2 Jts. HWDP. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Continue to rig up for spud. Pit level monitors.Shakers. Install duck pond between rock washer and pit complex. Familiarize crew members with the rig and equipment. Build containment for drum products.Work on shakers. 06:00 12:00 6.00 0 0 MIRU MOVE RURD P Obtain RKBs: MOB=11.00, GL=18.5, Landing Ring=24.00. Inspect Boiler and Fuel System. Install Boiler Exhaust Stack. Install hot well stack. Inspect SRL's. Barricade ODS Drawworks Mezzanine door.Cont.to install Comms. Install Gaitronics. Install Centrifuge stand.Test E-Stops on pump engines,drawworks and topdrive.Trouble shoot topdrive E-Stop. 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Certify all torque gauges on top drive and rig tongs. Finish rebuild all shaker beds.Mechanic worked on E stop for top drive. Prepare rock washer for spud. Prepare pits to take on water and build spud mud. Bring bit, bit sub,XO,to rig floor. Make up 12%"Reed MillTooth bit, bit sub,XO, 2 HWDP.Stand back. Calibrate pit level monitors. 06/01/2012 Complete rig acceptance checklist. Perform Diverter&Koomey test.Witness of test by AOGCC rep Bob Noble. Load pits with water,function test equipment again. Rig accepted at 1200 HRS.Mix spud mud. Page 5 of 6 • • Time Logs Date From To + Dur S. Depth E. Depth Phase Code ` Subcode T Comment 00:00 04:00 4.00 0 MIRU MOVE RURD P Replace Air Compressor pop offs, Check crown-o-matic, R/U Cement line, Finish R/U of Totco Rig Sense equipment 04:00 04:30 0.50 MIRU MOVE SFTY P Performed well control drills: 04:30 09:00 4.50 MIRU MOVE RURD P Cont.to R/U Gaitroncis,fabricate degasser gasket,function test diverter system, check handling equipment,bring DP pups over from A pad.Calibrate pit system w/Totco, Tighten bolts on Manual choke, Install rebuilt manual bean valve on choke manifold,&test gas alarms. 1, 09:00 12:00 3.00 MIRU MOVE SFTY P Performed diverter test as per AOGCC whitnessed by Bob Noble, V Performed Accumulator test: /k45 pressure prior to function=1500 psi, pressure after to function=1450 psi man., 1450 Accum., 1400 psi annular,Time to 200 psi=30 sec., time to full pressure=150 sec. Rig Released form from MOB to Rig acceptance at 1200 HRS. Report on drilling Network#. Page 6 of 6 • ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: BRU 242-04 Rig Name: DOYON ARCTIC FOX Job Type: DRILLING ORIGINAL Rig Accept: 6/1/2012 12:00:00 PM Rig Release: Time Logs Date _From To Our S. Depth E.Depth Phase Code Subcode I 'Comment 06/01/2012 24 hr summary Performed diverter test as per AOGCC Inspector Bob Noble, Performed Accumulator test:pressure prior to function= 1500 psi,pressure after to function=1450 psi man., 1450 Accum., 1400 psi annular,Time to 200 psi=30 sec.,time to full pressure= 150 sec. 00:00 12:00 12.00 0 MIRU MOVE MOB P Mobilze Rig 12:00 18:30 6.50 19 19 SURFA( DRILL COND P Rig accepted at 1200 HRS Mix spud mud. Prep BHA for spud. NOTE: Earlier, performed diverter test as per AOGCC whitnessed by Bob Noble, Performed Accumulator test: pressure prior to function= 1500 psi, pressure after to function= 1450 psi man., 1450 Accum., 1400 psi annular,Time to 200 psi=30 sec.,time to full pressure=150 sec. 18:30 19:30 1.00 19 65 SURFA( DRILL DRLG P Spud well with 180 GPM, 60 RPM, 1000 WOB, 100 PSI. Drill two singles of HWDP to allow for picking up drill pipe. .55 ART. Stand back one stand with bit still made up. 19:30 19:45 0.25 65 65 SURFA( DRILL SFTY P Pre Job meeting. Picking up and standing back drill pipe. 19:45 00:00 4.25 65 65 SURFA( DRILL PULD P Pick up and stand back 18 joints 5" HWDP. Pick up and stand back 92 joints 4"HT 38 DP. 06/02/2012 Drill from 66'to 217'MD. POOH. Make up BHA#3. MUD Motor assembly with MWD EM system. Drill from 217'to 617'MD. Lubricate rig, service toip drive, blocks, swivel. 00:00 01:15 1.25 65 65 SURFA( DRILL PULD P Pick up 14 joints of 4"HT 38. 01:15 02:30 1.25 66 66 SURFA( DRILL RURD P Change out handling equipment from 4"to 5", change elevators to 5". 02:30 04:30 2.00 66 145 SURFA( DRILL DRLG P Drill from 66.0'to 145.0'.400 GPM, 60 RPM,2k WOB.ART=1.50 HRS. 04:30 06:00 1.50 145 217 SURFA( DRILL DRLG P Drill from 145'to 217'MD.450 GPM, 90 RPM.2 to 4k WOB.Gravel,sand, clay.ART=1.25 HRS.ADT=3.35 HRS. 06:00 06:30 0.50 217 217 SURFA( DRILL CIRC P Condition mud. Circulate BU 2x's. 940 strokes @ 450 GPM.620 PSI. 06:30 08:15 1.75 217 217 SURFA( DRILL TRIP P Trip. POOH to BHA#2. Break out bit, bit sub,XO. Clean rig floor. 08:15 08:30 0.25 217 217 SURFA( DRILL SFTY P Prejob safety meeting on picking up BHA. 08:30 12:00 3.50 217 217 SURFA( DRILL PULD P Pick up BHA#3.Make up 8"Mud Motor assembly for kick off. Page 1 of 18 • • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 217 217 SURFA( DRILL PULD P Continue to pick up BHA#3.MWD EM system. Up load,and calibrate tools. Calibrate block height. 17:00 23:30 6.50 217 617 SURFA( DRILL DDRL P Directional drill from 217'to 617'MD. 450 GPM,80 RPM,2 to 10k WOB, 2-3k TQ, P/U Wt=58k,S/O Wt=58k, Rot Wt=58k,ART=2.93,AST=0.7, Jar Hrs=3.63.ADT=3.63. 23:30 00:00 0.50 617 617 SURFA( DRILL SVRG P Service Rig,topdrive,blocks,swivel. 06/03/2012 Directional Drill from 617'MD to 933'MD. Repair top drive rail. Directional Drill from 933'MD to 1184'MD. CBU 2 x's.Short trip 10 stands. Good hole conditions. Directional Drill from 1184'MD to 1813'MD. ECD=9.74 PPG. 00:00 00:45 0.75 617 617 SURFA( DRILL SVRG P Change out top drive saver sub from 4%"IFto4"HT38. 00:45 06:00 5.25 617 933 SURFA( DRILL DDRL P Directional drill from 617'to 933'MD. 450 GPM,80 RPM,2 to 10k WOB, 2-3k TQ, P/U Wt=62k, 5/0 Wt=62k, Rot Wt=62k,ART=.87,AST=1.30, Jar Hrs=5.8.ADT=2.17 06:00 07:00 1.00 933 933 SURFA( DRILL SVRG P Stand one stand back.Work on top drive rail. Loose pin.Circulate @ 250 GPM,350 PSI while performing repair.Trip back to bottom 07:00 11:00 4.00 933 1,184 SURFA( DRILL DDRL P Directional drill from 933'to 1184' MD.500 GPM, 80 RPM, 10 to 20k WOB,2-3k TQ, P/U Wt=73k,S/O Wt=62k, Rot Wt=65k,ART=0.5, AST=0.89,Jar Hrs=7.19 ADT=1.39 11:00 13:00 2.00 1,184 1,184 SURFA( DRILL CIRC T Circulate and condition mud. Prepare for 10 stand short trip.take check shot surveys for accuracy. Pull one stand.CBU 2 times. 500 GPM, 1100 PSI,50 RPM,34% Flow,2K Torque, P/U 68K, S/0 62K, ROT 65K.The hole unloaded. 13:00 14:00 1.00 1,184 1,184 SURFA( DRILL TRIP P Flow Check.TOOH F/1184'T/618'. change out elevators to 5".TOOH T/ collars.5-10K drag @ 888' 14:00 15:30 1.50 1,184 1,184 SURFA( DRILL TRIP P TIH T/618',change elevators to 4", TIH T/1184'. No fill on botom 15:30 18:00 2.50 1,184 1,374 SURFA( DRILL DDRL P Drill Actual F/1184'T/1374', PR 13 BPM, 1200 PSI on, 1120 off,80 RPM,4.2K Torque on, 1.1K torque off, 3-5K WOB, P/U 68K, S/0 62K, ROT 65K 18:00 00:00 6.00 1,374 1,813 SURFA( DRILL DDRL P Drill Actual F/1374'T/1813', PR 508 GPM,80 RPM, 8k WOB, 1370 PSI on, 1220 PSI off. P/U Wt=85k,S/0 Wt=62k, Rot Wt=70k.AST=3.04, ART=2.01,ADT=5.05,Jar hrs=12.24. 06/04/2012 Directional Drill from 1813'to 2190'MD.Circulate BU 2 X's. Short trip to 995'MD.TIH. Directional Drill from 2446'MD to 2757'MD.Service rig. Crew change. Page 2 of 18 • • Time Logs Date From To Dur S.Depth E.Depth?Phase Code Subcode T ;Comment 00:00 06:30 6.50 1,813 2,188 SURFA( DRILL DDRL P Drill Actual F/1813'T/2190', PR 550 GPM, 80 RPM, 10k WOB, 1650 PSI on, 1550 PSI off. P/U Wt=85k, S/O Wt=62k, Rot Wt=65k.AST=0.64, ART=2.97,ADT=3.61,Jar hrs=15.85 06:30 07:30 1.00 2,188 2,188 SURFA( DRILL CIRC P CBU 2 x's. Rotate and reciprocate the drill string.550 GPM,80 RPM. Prepare for short trip. 07:30 07:45 0.25 2,188 2,188 SURFA( DRILL OWFF P Observe the well. %barrel per hour loss rate. Seepage.Well not flowing. Line up to trip pipe. 07:45 12:00 4.25 2,188 1,311 SURFA( DRILL TRIP P Wiper trip. POOH from 2188 to 2065'.Good hole fill.Continue to POOH on elevators to 1659'. Encounter tight hole conditions. 10k over pull. 1659 to 1624'. 10k over 1600'to 1589'. 10k over 1558'.Stop. Begin to back ream. Back ream out to 1455'to 1440'MD. Pack offs seen. Began to back ream slow,to clean the hole up. Back ream to 1311'MD. Hole cleaned up. POOH on elevators. 12:00 12:30 0.50 1,311 995 SURFA( DRILL TRIP P POOH on elevators from 1311'to 995'.Good hole conditions. 12:30 13:30 1.00 995 2,188 SURFA( DRILL TRIP P Trip in the hole. No problems. No fill on bottom.A few bobbles seen of 5 to 10k. 13:30 18:00 4.50 2,188 2,446 SURFA( DRILL DDRL P Drill Actual F/2188'T/2446', PR 550 GPM,90 RPM, 15k WOB, 1800 PSI on, 1650 PSI off. P/U Wt=90k,S/O Wt=57k, Rot Wt=70k.AST=0.68, ART=1.36,ADT=2.04,Jar hrs=17.89 18:00 23:30 5.50 2,446 2,757 SURFA( DRILL DDRL P Drill Actual F/2446'T/2757', PR 560 GPM,90 RPM, 15k WOB,2030 PSI on, 1900 PSI off. P/U Wt=100k, 5/0 Wt=65k, Rot Wt=72k.AST=1.26, ART=1.91,ADT=3.17,Jar hrs=21.06 23:30 00:00 0.50 2,757 2,757 SURFA( DRILL SVRG P Service rig. Lubricate,top drive, swivel,blocks. 06/05/2012 Directional Drill from 2757'MD to 3346'MD.Circulate and condition wellbore. Conduct short trip out to 3072' MD. 00:00 06:00 6.00 2,757 2,946 SURFA( DRILL DDRL P Drill Actual F/2757'T/2946', PR 560 GPM,90 RPM, 15k WOB,2030 PSI on, 1900 PSI off. P/U Wt=110k,S/O Wt=64k, Rot Wt=73k.AST=1.26, ART=1.60,ADT=2.86,Jar hrs=23.92 Wash slide intervals,and double back ream each stand. Page 3 of 18 •_. • Time Logs Date . From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:00 12:00 6.00 2,946 3,136 SURFA( DRILL DDRL P Drill Actual F/2946'T/3136', PR 560 GPM,90 RPM, 15k WOB,2030 PSI on, 1900 PSI off. P/U Wt=107k,S/O Wt=65k, Rot Wt=77k.AST=2.02, ART=1.99,ADT=4.01,Jar hrs=27.93 Wash slide intervals,and double back ream each stand. Pump nut plug sweep, bit balling. Drilled thin coal beds. 12:00 18:00 6.00 3,136 3,334 SURFA( DRILL DDRL P Drill Actual F/3136'T/3334', PR 560 GPM,90 RPM, 15k WOB,2250 PSI on, 1900 PSI off. P/U Wt=115k,S/O Wt=70k, Rot Wt=85k.AST=2.45, ART=1.36,ADT=3.97,Jar hrs=31.90 Wash slide intervals,and double back ream each stand. 18:00 19:00 1.00 3,334 3,334 SURFA( DRILL CIRC P Wait on town Geologist to determine casing point. Rotate and reciprocate drill string. 555 GPM,2130 PSI,80 RPM. 19:00 20:00 1.00 3,334 3,346 SURFA( DRILL DDRL P Drill to TD.Slide. P/U Wt=115k,S/0 Wt=70k, Rot Wt=82k.AST=.16 20:00 22:00 2.00 3,346 3,346 SURFA( DRILL CIRC P Pump sweep,circulate surface to surface and one bottoms up. Hole cleaned up. 22:00 22:15 0.25 3,346 3,346 SURFA( DRILL OWFF P Observe well for flow.Static. PJSM on tripping pipe. 22:15 00:00 1.75 3,346 3,072 SURFA( DRILL TRIP P Pull 2 stands. No swabbing. Fill the hole. Good hole fill. Line up on trip tank. Pull 1/2 stand and pull tight. Pulled tight @ 3245'. Back ream 3 stands, @ 450 GPM,60 RPM. CBU. Crew change. 06/06/2012 Short trip to top of HWDP.TIH. Circulate and condition the mud. 3x's bottoms up. POOH on elevators.Good hole fill. Lay down BHA#3. Rig up to run 9 5/8"casing. 00:00 05:00 5.00 3,072 347 SURFA( DRILL TRIP P Short trip out to the top of the HWDP.Monitor the well for 15 mins.Conduct diverter drill. Install 5" elevators. Pull to the top of the collars.Calc fill=12.6 BBLs.Actual fill=14.0 BBLs. ✓ 05:00 06:00 1.00 347 347 SURFA( DRILL SFTY P Clean and clear rig floor. PJSM on tripping in the hole. Discuss how to monitor the pits,specific pinch points etc.. 06:00 10:00 4.00 347 3,292 SURFA( DRILL TRIP P Trip in the hole from 347 to 3292' MD. Fill pipe every 20 stands.Tight hole seen @ 1626'MD. Make up to TD and ream down from 3292'to 3346. No Fill. 10:00 12:00 2.00 3,292 3,346 SURFA( DRILL CIRC P Condition and circulate mud. Circulate bottoms up 3 x's. 550 GPM.60 RPM.TQ 6k.2150 PSI. The hole cleaned up nicely. 12:00 12:15 0.25 3,346 3,346 SURFA( DRILL OWFF P Observe well for flow.Static. Page 4 of 18 • • Time Logs Date From To Dur S. Depth E.Depth,Phase Code Subcode T Comment 12:15 16:00 3.75 3,346 660 SURFA( DRILL TRIP P Trip out of the hole from 3346'MD to HWDP.Conducting periodic check shot surveys. 16:00 16:30 0.50 660 660 SURFA( DRILL OWFF P Observe well for flow.Well static. PJSM on laying down BHA components. 16:30 20:00 3.50 660 0 SURFA( DRILL PULD P Lay down BHA#3. Down load tools. Grade the bit.Clean and clear rig floor. 20:00 22:00 2.00 0 0 SURFA(CASING RURD P Rig up to run 9 5/8"40#L80 BTC-M casing.Change bales and elevators. Make dummy run with landing joint and hanger.Measure 23.05 RKB to load shoulder. 22:00 22:30 0.50 0 0 SURFA( CASING SFTY P PJSM. Rigging up Weatherford casing equipment. 22:30 00:00 1.50 0 0 SURFA( CASING RURD P Rig up power unit. Pick up casing tongs,slips,false rotary table,dog collar,elevators. Run hydraulic hoses,and emergency air shut off. 06/07/2012 Run 9 5/8"L-80 40#BTC-M casing to 3334.83.Cement with 324 barrels class G cement 12.0 PPG.Cement to surface. 00:00 01:15 1.25 0 0 SURFA(CASING RURD P Continue rig up csg equipment. 01:15 01:30 0.25 0 0 SURFA( CASING SFTY P PJSM on running 9 5/8"csg. 01:30 07:00 5.50 0 1,285 SURFA(CASING RNCS P MU shoe jts. Install swedge and circulate through float equipment. RIH with 30 jts 9 5/8"40#L-80 BTCM csg to 1285'.One centralizer per jt. Filled pipe every 5 jts. 07:00 07:45 0.75 1,285 1,285 SURFA(CASINGCIRC P Circulate and condition mud at 185. gpm and 224 psi. Up Wt-77k. Dn Wt-55k 07:45 12:00 4.25 1,285 3,346 SURFA(CASING RNCS P Run from 1285'MD to 3346'MD. Torque all connections to 9500 ft/lbs. Fill every 5 joints. Ran 77 joints.3 stop rings.75 bow spring centralizers. 12:00 16:00 4.00 3,346 3,346 SURFA( CEMEN-CIRC P Condition and circulate, Reciprocate the casing.4.3 BPM.780 PSI ICP. Bottoms up. FCP 355 PSI. P/U Wt=170k,S/O Wt=68k. Increase flow up to 6.5 BPM.420 PSI. Up to 9 BPM.630 PSI. 16:00 16:30 0.50 3,346 3,346 SURFA(CEMEN-RURD P Install cement head with Baker Cementing crew on rig floor. 16:30 17:00 0.50 3,346 3,346 SURFA(CEMEN"SFTY P Pre job safety meeting with all crews. Cementing in the surface pipe. Discuss hazards.Trapped pressure from pumping.Trip hazards of all the hard line. Page 5 of 18 • �� Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment j 17:00 21:30 4.50 3,346 0 SURFA( CEMEN-CMNT P Cement 9 5/8"casing. L-80.40#. /$ BTC-M. Baker cementers: Pump 5 oS BBL spacer. Shut down. Pressure test to 3000 PSI. Pump 35 BBLs Mud Sweep.9.2 PPG. Pump 40 BBLs SAPP water/red dye. 10 BBL water. Drop plug. 324 BBLs 12 PPG., Class G cement.Drop 2nd plug. Pump 10 barrels water.Switch to Rig. Rig pumped:239.8 BBLs mud. 3561 strokes calc plus%the shoe track=3606 strokes.Shut down. FCP=960 PSI. Did not bump the plug. Hold 690 PSI for 15 mins. Bleed off, monitor well for 30 mins. Floats held. No back flow. Cement returns to the cellar. 5 barrels of cement back to surfa . Calculates to 13"hole average.) 21:30 00:00 2.50 0 0 SURFA(CEMEN"RURD P Hold PJSM. Rig down cement lines. Blow down to the cuttings tank. Baker Cement truck blew down to the cuttings tank. Break cement head out with TD. Lay down side door elevators. Nipple down cement head. Back out landing joint. Flush stack and cellar.Add cement inhibitor. Suck our cellar and stack with Peak Super Suckers. 06/08/2012 Rig down after cement job.Verify floats were good. N/D 21'/4'Hydril. N/U Vetco Multibowl,orient. N/U 11" Hydril BOP stack. 00:00 01:00 1.00 0 0 SURFA(CEMEN'RURD P Continue to rig down cement equipment from rig floor. Remove long bails. Suck out cellar box. SIMOPS:Clean pits. 01:00 02:00 1.00 0 0 SURFA( CEMEN'RURD P Rig up short bails. Peak crew continued to wash down, clean cellar box, and cuttings box. Rig down CatchKan,drip liner. Rig down Weatherford power unit and hoses. Remove turnbuckles on annular preventer. Rig up 4 point pick with slings to top drive. 02:00 06:00 4.00 0 0 SURFA(CEMEN-NUND P_ Nipple down surface stack. Blow down hole fill line,flow jet, bleeder line, remove from nipple. Remove riser bolts and lay down riser. Rig up 4 point sling to Hydril. 06:00 08:00 2.00 0 0 SURFA(WHDBO NUND P Nipple down surface stack. Hold PJSM: Removeing Riser. Back out lock down screws on riser. Pick riser off conductor,set Hydril and riser on sills. Rig up come-a-long to riser, remove riser studs and lay down riser. Set 15k lb 21%4'Hydril on cellar cart. Page 6 of 18 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 08:00 12:00 4.00 0 0 SURFA(WHDBO NUND P PJSM. Removing starter head with Vetco Wellhead hand. Remove starter head from conductor and install wellhead,(multibowl),with Vetco. 12:00 18:00 6.00 0 0 SURFA(WHDBO NUND P Clean out cellar.Continue to install wellhead with Vetco Rep.Verify orientation of valves with Co. Man. Attempt to test seal sleeve void. Failed. Remove wellhead and replace seal sleeve.Make up wellhead and retest.Good. 500 PSI low 5000 PSI high. 10 mins each.Measure RKB to wellhead. 17.47'. ULDS=17.62'. LLDS=19.47.SIMOPS: Cleaning pits,service top drive,and TD generator. Electrician fixed gaitronics in chokehouse, nipple down diverter line with crane crew,change liners in mud pumps to 5". 18:00 00:00 6.00 0 0 SURFA(WHDBO NUND P Nipple up BOP equipment.SIMOPS: Continue to clean pits. 06/09/2012 Finish nipple up BOP stack.Start BOPE test.SIMOPS: Build mud in pits,and @ BRWD. Bring in 110 joints 4"DP.Strap and tally 00:00 05:00 5.00 0 0 SURFA(WHDBO NUND P Continue NU BOPE.Change out upper rams to 2 7/8"X 5"VBR's. Test 2"Demco and kill line check valve to 250/5000 psi for 10 min. Change liners on mud pumps to 5". Continue cleaning pits. 05:00 09:30 4.50 0 0 SURFA(WHDBO NUND P MU lower ram section to stack. Install blooey line and. MU 1"valve in closing side of annular BOP.Take on fresh water in pits. 09:30 12:00 2.50 0 0 SURFA(WHDBO NUND P Set stack on well head.Tighten bolts to spec's.MU choke line to choke house. 12:00 16:30 4.50 0 0 SURFA(WHDBO NUND P Continue to nipple up BOPE. Page 7 of 18 S. ... • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 16:30 00:00 7.50 0 0 SURFA(WHDBO BOPE P Pick up and make up BOPE testing equipment.AOGCC Officer Jim Regg waived witness. BLM Rep.Tom Zelenka waived witness.Test#1: Annular to 250 psi low,3500 PSI high, 10 mins each test.Charted. Test all valves and rams to 250 PSI low,5000 PSI high, 10 mins each test.Charted.4"test joint used.Test #2: Upper variable pipe rams.2 7/8" Qv X 5",dart valve, HCR Kill,Choke manifold,#15,14,9,5,1.Test#3:TIW valve,inside manual kill,Choke manifold#4,8,12,13.Test#4: !BOP, Choke manifold#3,7,11.Test#5: Manual kelly,Choke manifold #2,6,10.Test#6 Choke side HCR. Test#7: Inside manual choke.Test #8: Lower solid body 4"pipe rams. 06/10/2012 Complete BOPE testing. Pick up Sperry BHA#4. Mud Motor,quad combo MWD tools,TIH with 110 joints of 4"DP. 00:00 01:30 1.50 0 0 SURFA(WHDBO BOPE P Koomey test.System pressure=3000 PSI. Pressure after closed=1650 PSI.200 PSI attained in 24 secs. Full Pressure attained in 1 min 55 secs.6 Nitrogen bottles average=2350 PSI.Test#10. Blind rams.250 PSI low 10 mins.5000 PSI high 10 mins.Charted. 01:30 05:00 3.50 0 0 SURFA(WHDBO OTHR P Pull test plug. Install 9_.125"wear bushing. Installed kill line and check valve. Install riser and flowline. Record RKB measurements. 05:00 09:30 4.50 0 0 SURFA(WHDBO SEQP P Performed body test on kill line and check valve. Function test injection pump. Blow down choke manifold and kill line. MU floor safety valve to XO. 09:30 10:00 0.50 0 0 SURFA( DRILL PULD P Move small BHA components to rig floor. 10:00 10:15 0.25 0 0 SURFA( DRILL SFTY P PJSM on MU BHA. 10:15 12:00 1.75 0 0 SURFA( DRILL PULD P Change elevators. PU mud motor and MU bit. 12:00 16:00 4.00 0 156 SURFA( DRILL PULD P PJSM. Pick up BHA.Make up float sub/stab/DM collar/4 Phase Res/ PWD/Density/Neutron/EM/ Antenna sub/Up load. 16:00 16:30 0.50 156 156 SURFA( DRILL SFTY P Evacuation drill. 16:30 18:00 1.50 156 187 SURFA( DRILL PULD P Pick up Bat Sonic tool. Up load. 18:00 18:15 0.25 187 187 SURFA( DRILL SFTY P PJSM. Loading nuclear sources into the MWD tools. 18:15 19:30 1.25 187 187 SURFA( DRILL PULD P Load sources. 19:30 20:00 0.50 187 187 SURFA( DRILL SVRG P Service Rig. Lubricate. Repair hydraulic hose on pipe spinners. Page 8 of 18 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 20:30 0.50 187 674 SURFA( DRILL PULD P Trip in the hole with 5"HWDP 20:30 21:00 0.50 674 674 SURFA( DRILL SFTY P PJSM. Picking up 4"DP. 21:00 23:00 2.00 674 1,876 SURFA( DRILL PULD P Pick up singles out of the pipeshed. 4"HT 38.40 joints of 4"DP 23:00 23:45 0.75 1,876 1,876 SURFA( DRILL CIRC P Circulate bottoms up @ 125 GPM, 650 PSI. 23:45 00:00 0.25 1,876 2,348 SURFA( DRILL PULD P Pick up 15 joints of 4"DP.Crew change. 5.25 BBLS Actual displacement for 15. 5.25 BBLS calculated. 06/11/2012 Pick up 110 joints of 4"DP.Trip to 3126'MD. Circulate and condition the mud. Perform casing test. Drill the float ecuipment and shoe track plus 20 feet of new hole. C&C. Rig up to perform LOT. 00:00 01:30 1.50 2,348 2,811 SURFA( DRILL SFTY P PU and RIH with 4"DP from 2811'to 2874' 01:30 03:30 2.00 2,811 2,874 SURFA( DRILL PULD P PJSM. Kick while tripping drill. Strip in 2 jts DP. POH remove IBOP and TIW. Function test injection pump. 03:30 06:00 2.50 2,874 2,874 SURFA( DRILL CIRC P Circ and condition mud at 3 bpm. Service top drive. 06:00 08:00 2.00 2,874 1,621 SURFA( DRILL TRIP P POOH and std back 20 stds 4"DP. Clean rig floor. 08:00 11:30 3.50 1,621 3,126 SURFA( DRILL PULD P PU and RIH wit 38 jts 4"DP. RIH with 5 stds from derrick.to 3126'. 11:30 12:00 0.50 3,126 3,126 SURFA( DRILL CIRC P Circ and condition mud at 300 gpm- 825 psi-40 rpm. 12:00 14:00 2.00 3,126 3,126 SURFA( DRILL CIRC P Condition the mud system.9.6 PPG in and out. 14:00 14:15 0.25 3,126 3,126 SURFA( DRILL SFTY P PJSM on rigging up to test the casing. 14:15 15:30 1.25 3,126 3,126 SURFA( DRILL PRTS P Pressure test the casing to 3000 PSI.Charted.Good. 15:30 16:30 1.00 3,126 3,126 SURFA( DRILL SLPC P Cut 64'of drilling line.Slip. Recalibrate block height. 16:30 17:00 0.50 3,126 3,126 SURFA( DRILL SVRG P Service the rig.Change out dies in the top drive. 17:00 17:30 0.50 3,126 3,252 SURFA( DRILL CIRC P TIH from 3126'MD to 3252'MD.Tag top plug.Top of float=3253'MD.The plug was one foot away. 17:30 21:00 3.50 3,252 3,346 SURFA( DRILL CIRC P Drill out float equipment,cement, shoe,ream to bottom. 325 GPM, 940 PSI,60 RPM, 8k TQ, 10k WOB. 21:00 21:30 0.50 3,346 3,366 SURFA( DRILL DDRL P Drill from 3346 to 3366'MD.325 GPM, 1000 PSI,70 RPM,8K TQ, 10k WOB, 21:30 22:00 0.50 3,366 3,366 SURFA( DRILL CIRC P Circulate and condition the mud system to even out the mud weight. 9.6 PPG in and out. 22:00 22:30 0.50 3,366 3,366 SURFA( DRILL SFTY P PJSM>Perform LOT/FIT.With injection pump.Stand back one stand. 22:30 00:00 1.50 3,366 3,366 SURFA( DRILL LOT P Rig up to test equipment for FIT. Trouble shoot injection pump. 06/12/2012 Perform leak off test, (establish 15.7 PPD EMW)clean rig and pits, rig down test equipment, prep rock washer f/displacement,displace w/9.6 KLA-Sheild mud,drill to 3551,trouble shoot electrical problem on TD, drill to 3567',trip out of hole to shoe,work on top drive. Page 9 of 18 • • . Time Logs Date From To Dur S.Depth E.Depth Phase Code ' Subcode T ?Comment 00:00 01:00 1.00 3,366 3,366 SURFA( CEMEN"LOT P Perform LOT. Establish 15.7 PPG 01:00 02:30 1.50 3,366 3,366 PROD1 DRILL OTHR P Clean rig and pits. RD test equipment. Blow down choke manifold and lines. Prep rock washer for displacement. 02:30 03:00 0.50 3,366 3,366 PROD1 DRILL SFTY P PJSM with all personnel on displacing well to 9.6 ppg Kla-Sheild. 03:00 04:30 1.50 3,366 3,366 PROD1 DRILL CIRC P Pumped 40 bbl hi vis spacer. Displace well to 9.6 ppg Kla-Shield mud. 04:30 05:00 0.50 3,366 3,366 PROD1 DRILL OTHR P Clean shakers and troughs. 05:00 11:30 6.50 3,366 3,551 PROD1 DRILL DDRL P Drill 8 3/4"hole from 3366'to 3551' MD.3036'TVD ADT-2.79 hrs ART-1.19 hrs AST -1.60 hrs Bit wt-5K Flow rate 300-400 gpm @ 910 psi Up wt-125k Dn wt-70 k Rot wt- 90k Torque On-8k Off-4K Note:Still in process of hauling off spud mud from pits. Drilling with reduced flow rate to prevent contamination with new mud. 11:30 12:00 0.50 3,551 3,551 PROD1 DRILL SVRG P Service rig. 12:00 13:00 1.00 3,551 3,551 PROD1 DRILL RGRP T Trouble shooting electrical problem on top drive. 13:00 13:30 0.50 3,551 3,567 PROD1 DRILL DDRL P Drill F/3551'T/3567 PR @ 400 GPM 13:30 14:30 1.00 3,567 3,567 PROD1 DRILL SRVY P Dir.work conduct survey as per DD. 14:30 15:00 0.50 3,567 3,567 PROD1 DRILL TRIP T Trip out of hole to shoe to trouble shoot top drive electrical problem, monitor well on T.T 15:00 00:00 9.00 3,567 3,567 PROD1 DRILL EQRP T Trouble shooting electrical problem on top drive. 06/13/2012 Drill 8 3/4 production hole T/3944,TOH to shoe,circulate and observe well,Safety Stand down(Finger and hand injury review)TIH,drill 8 3/4 production hole F/3944 T/45875', 00:00 00:30 0.50 3,567 3,567 PROD1 DRILL SFTY P Pre tour safety meeting. 00:30 09:00 8.50 3,567 3,944 PROD1 DRILL DDRL P Rotate and slide F/3567'T/3944'- 377 @ 44.3 ft/hr', 09:00 10:00 1.00 3,944 3,944 PROD1 DRILL CIRC P Circulate bottoms up and PJSM on tripping out of hole. 10:00 11:00 1.00 3,944 3,944 PROD1 DRILL TRIP P Monitor well and trip out of hole to shoe @ 3316 11:00 12:00 1.00 3,944 3,944 PROD1 DRILL CIRC P Install TIW valve,circulate over top of hole with hole fill pump and monitor G/L 12:00 14:00 2.00 3,944 3,944 PROD1 DRILL SFTY P Safety stand meeting, Hand and Finger Injury and Awareness 14:00 14:30 0.50 3,944 3,944 PROD1 DRILL TRIP P Trip in hole Page 10 of 18 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T 'Comment 14:30 23:30 9.00 3,944 4,575 PROD1 DRILL DDRL P Drill F/3944 T/4575-631'@70.0 ft/hr 23:30 00:00 0.50 4,575 4,575 PROD1 DRILL DDRL P Service top drive and rig 06/14/2012 Rotate and slide to 5014,circulate bottoms up, PJSM,monitor well TOH to 4575',Trip in hole F/4575 T/ 4953, ream F/4953 T/5014,rotate and slide F/5014 T/5770 00:00 00:30 0.50 4,575 4,575 PROD1 DRILL SFTY P Pre tour safety meeting 00:30 07:30 7.00 4,575 5,014 PROD1 DRILL DDRL P Monitor well and Rotate and slide F/ 4575 T/5014-439''@ 58.5 ft/hr 409 GPM, 1390 PSI on bottom 07:30 09:30 2.00 5,014 5,014 PROD1 DRILL CIRC P circulate bottoms up 09:30 11:00 1.50 5,014 5,014 PROD1 DRILL TRIP P PJSM, monitor well TOH to 4575' 11:00 11:30 0.50 5,014 5,014 PROD1 DRILL TRIP P Trip in hole F/4575 T/4953 11:30 12:00 0.50 5,014 5,014 PROD1 DRILL REAM P Ream F/4953 T/5014 12:00 00:00 12.00 5,014 5,770 PROD1 DRILL DDRL P Rotate and slide F/5014 T/5770- 756'@ 63 ft/hr PR @ 9.64 BPM, 1600 psi on bottom, 14700 psi off bottom 06/15/2012 Circulate bottoms up and clean hole, PJSM,flow check well and trip out of hole to 5014,trip in hole to 5957, wash and ream F/5957 T/6021, rotate and slide F/6021 T/6586 00:00 06:00 6.00 5,770 6,021 PROD1 DRILL DDRL P Rotate and slide F/5770 T/6021- 251'@ 41.8 ft/hr,404 GPM, 1630 PSI on bottom, 1450 off bottom 06:00 07:00 1.00 6,021 6,021 PROD1 DRILL CIRC P Circulate bottoms up and clean hole, 218 SPM,423 GPM,75 RPM 07:00 08:00 1.00 6,021 6,021 PROD1 DRILL TRIP P PJSM,flow check well and trip out of hole to 5014 08:00 09:30 1.50 6,021 6,021 PROD1 DRILL TRIP P Trip in hole to 5957,wash and ream F/5957 T/6021 09:30 00:00 14.50 6,021 6,586 PROD1 DRILL DDRL P Rotate and slide F/6021 T/6586, 06/16/2012 Pre Tour Safety meeting, rotate and slide F/6586 T/6775-189'@ 34.3 ft/hr,rotate and slide F/6775 T/7221- 446'@ 46.9 ft/hr,circulate&condition hole, pump 1 bottoms up, pump 40 bbl hi vis sweep,continue circulating F/two bottoms up @ 400 GPM, 1700 PSI,monitor well,trip out of hole 5 stands,pump dry job, continue pulling out of hole F/6903 T/4103-pulling 15 T/35K over F/6526 T/6274, work tight area& continue out T/4040',back ream F/4040 T/4008,continue trip out,T/3693, Back ream F/3693 T/3630' 00:00 00:30 0.50 6,586 6,586 PROD1 DRILL SFTY Pre tour safety meeting 00:30 06:00 5.50 6,586 6,775 PROD1 DRILL DDRL P Rotate and slide F/6586 T/6775- 189'@ 34.3 ft/hr, PR @ 460 GPM, 2210 PSi on bottom&1970 PSi off bottom 06:00 15:30 9.50 6,775 7,221 PROD1 DRILL DDRL P Rotate and slide F/6775 T/7221- 446'@ 46.9 ft/hr, PR @ 450 GPM, 2230 PSi on bottom&1870 PSi off bottom 15:30 18:30 3.00 7,221 7,221 PROD1 DRILL CIRC P Circulate&condution hole,pump 1 bottoms up, pump 40 bbl hi vis sweep,continue circulating F/two bottoms up @ 400 GPM, 1700 PSI, monitor well 18:3G 19:00 0.50 7,221 7,221 PROD1 DRILL TRIP P Trip out of hole 5 stands F/7219 T/ 6903' Page 11 of 18 Time Logs Date From To Dur S.Death E.Death Phase Code Subcode T Comment 19:00 19:30 0.50 7,221 7,221 PROD1 DRILL CIRC P Pump Dry job 19:30 22:30 3.00 7,221 7,221 PROD1 DRILL TRIP P Continue pulling out of hole F/6903 T/4103-pulling 15T/35Kover F/6526 T/6274, work tight area& continue out T/4040' 22:30 00:00 1.50 7,221 7,221 PROD1 DRILL REAM P Back ream F/4040 T/4008,continue trip out,T/3693, Back ream F/3693 T/3630 06/17/2012 POH on trip tank from 3630'to 3316',CBU.clean rig floor, RIH from 3316'to 7093'. Ream out tight spots at 6410',6948'and 7029',wash and ream tight hole from 7093'to 7221',CBU. Pump 30 bbl hi-vis sweep.CBU 2X, POH to shoe,service rig,top drive and back up generator,trip in hole F/3253 T/7156',fill pipe every 22stds.wash and ream F/7156 T/7219', CBU 2X, PJSM,drop rabbit&pull out of hole 5 stands, pump dry job, continue tripping out of hole. 00:00 01:30 1.50 3,630 3,316 PROD1 DRILL TRIP P POH on trip tank from 3630'to 3316'. 01:30 02:00 0.50 3,316 3,316 PROD1 DRILL CIRC P CBU.Clean rig floor. 02:00 06:00 4.00 3,316 7,093 PROD1 DRILL TRIP P RIH from 3316'to 7093'. Ream out tight spots at 6410',6948'and 7029'. 06:00 07:30 1.50 7,093 7,221 PROD1 DRILL REAM P Wash and ream tight hole from 7093' to 7221'. 07:30 09:00 1.50 7,221 7,221 PROD1 DRILL CIRC P CBU. Pump 30 bbl hi-vis sweep. CBU 2X at 425 gpm-1870 psi. 09:00 13:00 4.00 7,221 3,253 PROD1 DRILL TRIP P POH to shoe on trip tank. No hole problems. 13:00 14:00 1.00 3,253 3,253 PROD1 DRILL SVRG P Service rig,top drive and back up generator 14:00 17:30 3.50 3,253 7,221 PROD1 DRILL TRIP P Trip in hole F/3253 T/7156',fill pipe every 22stds.wash and ream F/7156 T/7219' 17:30 19:00 1.50 7,221 7,221 PROD1 DRILL CIRC P Circulate and condition hole, circulate 2 BTU @ 400 GPM w/ 1800PSI 19:00 19:30 0.50 7,221 7,221 PROD1 DRILL TRIP P Pre job safety meeting,drop rabbit& pull out of hole 5 stands 19:30 20:00 0.50 7,221 7,221 PROD1 DRILL TRIP P Pump dry job 20:00 00:00 4.00 7,221 7,221 PROD1 DRILL TRIP P Continue tripping out of hole 06/18/2012 Trip out of hole to BHA, Remove R/A source, Down load MWD,lay down BHA,stand back flex collars in derrick, circulate over top of hole&monitor losses, (1 BBL per hour losses),clean rig floor, P/U Haliburton sheasves and tools, PJSM W/Halliburton&hang sheaves, PJSM, pick up logging tools,test tools, no test, change out tools, retest OK,Trip in hole to shoe, PJSM W/all personnel on P/U side entry sub 00:00 02:00 2.00 7,221 7,221 PROD1 DRILL TRIP P Trip out of hole F/2249 T/705,flow check well 02:00 04:30 2.50 7,221 7,221 PROD1 DRILL TRIP P TOOH w/HWDP 04:30 06:00 1.50 7,221 7,221 PROD1 DRILL TRIP P PJSM,TOH W/BHA 06:00 09:30 3.50 7,221 7,221 PROD1 DRILL TRIP P PJSM,on removing R/A source, remove R/A source,download MWD, continue TOH 09:30 11:00 1.50 0 0 PROD1 DRILL CIRC P Circulate over top of hole&monitor losses, (1 BBL per hour losses), clean rig floor, P/U Haliburton sheasves and tools Page 12 of 18 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:00 13:00 2.00 0 0 PROD1 EVALFN SFTY P PJSM w/all personnel and third party employees, hang wireline sheave 13:00 18:00 5.00 0 0 PROD1 EVALFN DLOG P PJSM, pick up logging tools,Test tools, no test,change out tools, retest OK 18:00 23:00 5.00 3,307 4,283 PROD1 EVALFN DLOG P Trip in hole W @/HWDP,(Rabbit HWDP),continue tripping in hole with drill pipe,filling every 15 stds, monitor well @ shoe,continue tripping in @ 25'min 23:00 00:00 1.00 4,283 4,283 PROD1 EVALFN SFTY P PJSM,W/Halliburton on rigging up w/line sheaves&bring remaining XO's T/rig floor 06/19/2012 Rig up W/line,and side entry sub, Continue RIH with DP conveyed logs F/4282 T/6579,continue RIH with DP conveyed logs F/6579't/7000', POOH with drill pipe conveyed logs F/7000 T/5383,per Halliburton Logging-25 sets completed 4 more sets left on 1st run 00:00 02:00 2.00 4,283 4,283 PROD1 DRILL DLOG P Rig up W/line and side entry sub, RIH w/wire line and latch up 02:00 12:00 10.00 4,283 6,579 PROD1 DRILL DLOG P Continue RIH with DP conveyed logs F/4282 T/6579', monitor well F/G/L, while circulatine over hole W/trip tank 12:00 16:30 4.50 6,579 7,000 PROD1 DRILL DLOG P Continue RIH with DP conveyed logs F/6579't/7000'- monitor well F/ G/L,while circulatine over hole W/ trip tank 16:30 00:00 7.50 7,000 6,356 PROD1 DRILL DLOG P POOH with drill pipe conveyed logs F/7000 T/6356,per Halliburton,up wt, 130K-DN 85K,fluid loss F/tour =2bbl 06/20/2012 Pre Tour safety meeting,continue pullin out of hole W/DP convey log F/6356 T/4880,continue pullin out of hole W/DP convey log F/4880 T/4775',continue DP conveyed logs T/4783,pull out hole w/logging tools F/4783 T/4282', pull W/Line out of hole,break down side entry sub,pull out of hole T/2865', break circulation,make up side entry sub @ 2834'(75 jts), run in hole W/wire line and latch up,continue running in hole w/conveyed logs F/2834 T/3712 ✓ 00:00 00:30 0.50 6,356 6,356 PROD1 DRILL SFTY P Pre Tour safety meeting 00:30 06:00 5.50 6,356 4,880 PROD1 DRILL DLOG P Continue pullin out of hole W/DP convey log F/6356 T/4880.0 06:00 12:00 6.00 4,880 4,775 PROD1 DRILL DLOG P Continue pullin out of hole W/DP convey log F/4880 T/4775', P/u wt. 110-Sf074K 12:00 12:30 0.50 4,775 4,783 PROD1 DRILL SFTY P Continue DP conveyed logs T/4783 12:30 13:30 1.00 4,783 4,282 PROD1 DRILL DLOG P Pull out hole w/logging tools F/4783 T/4282'-P/U wt 75K S/O 55K 13:30 14:30 1.00 4,282 4,282 PROD1 DRILL DLOG P Pull W/Line out of hole, break down side entry sub 14:30 16:30 2.00 4,282 2,865 PROD1 DRILL DLOG P Pull out of hole F/4282 T/2865'@ 22'min. 16:30 17:00 0.50 2,865 2,865 PROD1 DRILL CIRC P Break circulation @ 3 bb/min 1500 PSI 17:00 18:30 1.50 2,865 2,834 PROD1 DRILL DLOG P Make up side entry sub @ 2834'(75 jts), run in hole W/wire line and latch up-400 gpm @ 700 psi Page 13 of 18 •, • Time Logs Date From To Dur S.Depth E.Depth Phase-"Code Subcode T Comment 18:30 00:00 5.50 2,834 3,712 PROD1 DRILL DLOG P Continue running in hole w/conveyed logs F/2834 T/3712, P/U wt 82K S/o 55K,7 bbl mud loss F/tour 06/21/2012 Continue RIH w/drill pipe conveyed logs F/3712 T/4125'MD,complete logging @ 4021 MD,trip out of hole to side entry sub @ 2834', unlatch F/tools,TOH w/wire line, remove side entry sub, rig down wire line sheaves&wire line equipment,trip out of hole F/2834 to logging tools, Lay down logging tools,clean rig floor, service rig, change out link tilt cylinder on T.D, pick up clean out assembly,TIH to shoe, 00:00 00:30 0.50 3,712 3,712 PROD1 DRILL SFTY P Pre tour meeting 00:30 06:00 5.50 3,712 4,125 PROD1 DRILL DLOG P Continue RIH w/drill pipe conveyed logs F/3712 T/4125'MD,@ 25 ft/min 06:00 08:30 2.50 4,125 4,021 PROD1 DRILL DLOG P Complete logging @ 4021 MD 08:30 10:30 2.00 4,021 2,834 PROD1 DRILL DLOG P Trip out of hole to side entry sub @ 2834' 10:30 12:00 1.50 2,834 2,834 PROD1 DRILL DLOG P PJSM, unlatch F/tools,TOH w/wire line, remove side entry sub, 12:00 13:30 1.50 2,834 2,834 PROD1 DRILL DLOG P Rig down wire line sheaves&wire line equipment. 13:30 17:00 3.50 2,834 135 PROD1 DRILL DLOG P Trip out of hole F/2834 to logging tools 17:00 19:00 2.00 0 0 PROD1 DRILL DLOG P PJSM, Lay down logging tools,clean rig floor 19:00 19:30 0.50 0 0 PROD1 DRILL SVRG P Service top drive and rig 19:30 20:30 1.00 0 0 PROD1 DRILL RGRP P Change out cylinder on link tilt on top drive. 20:30 22:30 2.00 0 0 PROD1 DRILL PULD P PJSM,pick up clean out assembly. 22:30 00:00 1.50 0 895 PROD1 DRILL TRIP P Trip in hole W/clean out assembly 06/22/2012 RIH w/clean ot assembly,circulate bottoms up @ 3348',cut and slip drilling line,continue tripping in hole, wash&ream F/6714 T/6746,trip in hole F/6746 T/6966,wash and ream F/6966 T/7221,circulate and condition mud, monitor well, PJSM, POOH to 6872,continue tripping out of hole, F/6872-over pull F/6872 T/6557 25/45K,pulled 30K over @ 5450,continue trip out to 3284',monitor well, Bop Drill,continue tripping out of hole to 579', lay down BHA, P/u test jt&wear ring puller. 00:00 02:30 2.50 895 3,348 PROD1 DRILL TRIP P RIH w/clean ot assembly 02:30 03:00 0.50 3,348 3,348 PROD1 DRILL CIRC P Circulate bottoms up @ 3348' 03:00 04:00 1.00 3,348 3,348 PROD1 DRILL SVRG P Cut and slip drilling line,(cut 120') 04:00 06:30 2.50 3,348 6,714 PROD1 DRILL TRIP P Continue tripping in hole F/3348 T/3567, Survey F/JORPS continue TIH T/6714' 06:30 09:00 2.50 6,714 6,746 PROD1 DRILL REAM P Wash&ream F/6714 T/6746 09:00 09:30 0.50 6,746 6,966 PROD1 DRILL TRIP P Trip in hole F/6746 T/6966 09:30 10:30 1.00 6,966 7,221 PROD1 DRILL REAM P Wash and ream F/6966 T/7221,@ 430G PM 1330 PSI 10:30 14:00 3.50 7,221 7,221 PROD1 DRILL CIRC P Circulate and condition mud @ 430 GPM, 1800 PSI, P/U 170K,S/O 105 Reciprocate drill string. ROT WT= 135K 14:00 14:30 0.50 7,221 6,872 PROD1 DRILL TRIP P Monitor well, PJSM, POOH to 6872, monitor well F/swabbing, pump dry job Page 14 of 18 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 14:30 18:00 3.50 6,872 3,284 PROD1 DRILL TRIP P Continue tripping out of hole, F/6872 -over pull F/6872 T/6557 25/45K, pulled 30K over @ 5450,Work tight spot&continue trip out to 3284' 18:00 18:30 0.50 3,284 3,284 PROD1 DRILL OTHR P Monitor well at the shoe, BOP Drill, inspect derrick. 18:30 20:30 2.00 3,284 579 PROD1 DRILL TRIP P Continue tripping out of hole to 579', monitor well at the BHA, PJSM on UD BHA 20:30 22:30 2.00 579 0 PROD1 DRILL PULD P Lay down HWDP,Jars,&drill collars,drain mud motor. 22:30 23:30 1.00 0 0 PROD1 DRILL PULD P Pull tool out of EM collar, UD MWD tools 23:30 00:00 0.50 0 PROD1 DRILL OTHR P Pick up test joint and wear ring puller. 06/23/2012 Pull wear bushing,change top rams F/2 7/8 T/ 7",pick up test joint and test 7"rams @ 4500 psi F/5 min, make dummy run with hanger through BOP'S, Rig up to run 7", Run 7"production casing per running order, P/u shoe track, baker lock 1st 3 jts.check floats,fill every jt RIH,top off every 10 jts, RIH F/103 T/2155'up wt 70K DWN 60K, run 7"26#casing F/2155 T/3196, break circulation @ 3196, @ 3BPM,W/160 PSI, increase T/4.5 BPM @ 170 PSI, increase rate to 5 BPM, losing returns, POOH lay down casing F/3196 T/2593, circulate @ 2593, regain partial return @ 3 BBUMIN with bleeder open,close bleeder, partial returns with bleeder closed, losing 2 bbls F/every 3 pumped, mix 30 bbl LCM pil and spot @ 2593, pull out of hole laying down 7"csg F/2593 T/2386 00:00 01:00 1.00 0 0 PROD1 CASING OTHR P Open blind rams, RIH W/wear ring puller,drain stack&suck out cellar. 01:00 02:00 1.00 0 0 PROD1 CASING OTHR P Back out lock down screws and pull wear busning, UD wear bushing& joint of pipe 02:00 03:30 1.50 0 0 PROD1 CASING BOPE P Change top rams F/2 7/85/_7",_ pick up test joint and test 7"rams @ 4500 psi F/5 min. 03:30 05:00 1.50 0 0 PROD1 CASING RNCS P P/U landing jt W/hanger,drain stack, make dummy run with hanger through BOP'S, mark landing joint W/hanger in spool(Vetco Grey Present), lay down landing jt. 05:00 06:30 1.50 0 0 PROD1 CASING RNCS P PJSM, R up to Jun 7"casing bring centrilzers&cement head to floor 06:30 12:00 5.50 103 2,155 PROD1 CASING RNCS P Run 7"production casing per running order, P/u shoe track, baker lock 1st 3 jts.check floats,fill every jt RIH, top off every 10jts, RIH F/103 T/2155' up wt 70K DWN 60K 12:00 14:30 2.50 2,155 3,196 PROD1 CASING RNCS P Run 7"26#casing F/2155 T/3196 14:30 16:30 2.00 3,196 3,196 PROD1 CASING CIRC T Break circulation @ 3196,@ 3BPM, W/160 PSI, increase T/4.5 BPM @ 170 PSI, increase rate to 5 BPM, losing returns 16:30 18:30 2.00 3,196 2,593 PROD1 CASING RNCS T POOH lay down casing F/3196 T/2593 18:30 23:00 4.50 2,593 2,593 PROD1 CASING RNCS T Try to regain circulation @ 2593, regain partial return @ 3 BBUMIN with bleeder open, close bleeder, partial returns with bleeder closed, losing 2 bbls F/every 3 pumped, mix 30 bbl LCM pil and spot @ 2593 Page 15 of 18 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:00 00:00 1.00 2,593 2,386 PROD1 CASING RNCS T Pull out of hole laying down 7"csg F/ 2593 T/2386 Total mud losses 296 bbls 06/24/2012 Continue pulling out of hole LID casing F/2386 T/103, LID shoe track,static loss rate @ shoe track=4 BBUHR, rig down csg runing equipment&rig up to test bop's,Test BOP's- Test rams,annular,choke manifold,floor valves and top drive valves @ 250 low 5000 high F/10 min ea, rig down testing equipment, blow down choke, kill and all surface lines, PJSM, Rig up to run 7"casing, Run 7"26#, L-80, BTCM casing T/ 854' 00:00 07:45 7.75 2,386 103 PROD1 CASING RNCS T Continue pulling out of hole LID casing F/2386 T/103, LID shoe track, static loss rate @ shoe 4 BBUHR 07:45 10:00 2.25 0 0 PROD1 CASING BOPE P Rig down csg running equipment, rig up tongs, r/u fill up line to annulas to fill hole during BOP test, M/U test fitting to top drive, P/U 7"test jt,fill stack,test joint and choke W/ water,build 375 bbls 9.7 PPG drilling mud 10:00 19:00 9.00 0 0 PROD1 CASING BOPE P Test BOP's- Test rams,annular, choke manifold,floor valves and top drive valves @ 250 low 5000 high F/ 10 min ea. Witness of test waived by AOGCC Bob Noble 19:00 20:00 1.00 0 0 PROD1 CASING BOPE P Rig down testing equipment,blow down choke,kill and all surface lines -Lost 3 bbls while testing 20:00 21:00 1.00 0 0 PROD1 CASING RNCS P PJSM, Rig up to run 7"casing. 21:00 00:00 3.00 0 854 PROD1 CASING RNCS P Pick up and run 7"26#, L-80, BTCM casing T/854" p/u wt.50K s/o 43k 06/25/2012 Pre tour safety meeting, Run 7"casing, F/854 T/3195,break circulation @ 982-65 spm-85 PSI-10% returns,continue running casing circulating every 1000'T/shoe, pump LCM pill,continue RIH T/4043'pump Icm pill out of pipe, continue running csg circulating every 1000/1500',Continue RIH to 7183 circulating every 1500',p/u landing joint, make up cement head&continue circulating&conditioning mud 00:00 00:30 0.50 854 854 PROD1 CASING RNCS P Pre tour safety meeting. 00:30 09:30 9.00 854 3,195 PROD1 CASING RNCS P Run 7"casing F/854 T/3195,break circulation @ 982—:65 spm-85 PSI- 10%returns-1 bbl loss, @ 1534', circulate @ 65spm, 120 psi, 10% returns,o bbl loss @ 2001'circulate @ 65 spm, 137 PSI, 10%flow out- 0 bbl loss, @ 3195'circulate w/65 spm-180 psi, 9%flow out,o losses,p/u 94 K-s/o 78K @ shoe, centralizer every third joint,2-3 min running speed 09:30 12:30 3.00 3,195 4,043 PROD1 CASING RNCS P Run 7"F/3195 T/3617',circulate& cond mud,65 spm @ 200 psi,9% flow out,spot 30 bbls LCM pill, chase w/868 stks, continue running casing T/4043, pump 2500 stks, @ 65 spm,240 psi,9%flow out,p/u wt. 120K-s/o 90 K Page 16 of 18 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T `Comment 12:30 23:00 10.50 4,043 7,183 PROD1 CASING RNCS P Continue running 7"F/4043,T/ 4424,circulate @ 3 BPM,W/240 psi, P/u wt 125,s/o 95 0 losses, RIH T/4851',circulate @ 3 bpm, @ 290 psi,0 losses, RIH T/5227', circulate @ 3 bpm, no losses,circulate @ 6120 @ 3 bpm, no losses,circulate @ 6754', @ 3bpm, no losses, circulate @ 7183' @ 3 bpm,W/540 PSI,p/u wt 197,s/o 125,9%flow returns, no losses 23:00 00:00 1.00 7,183 7,221 PROD1 CASING RNCS P Pick up landing jt, make up cement head, resume circulating and reciprocate pipe @ 7221' cal.displ F/casing=68 bbls,act displ=55 Loss of 13bbls 06/26/2012 Continue circulate&condition mud while reciprocate casing string. Rig up and batch mix cement as per BJ. Batch mixed 157 BBLS. Held PJSM. Mix and pump 40 BBL Mud Push,followed with 157 BBLS of 12 PPG cement. Displace cement and bump plug with 222 BBLS of 9.7 PPG brine. Pressure up on floats to 1300 PSI.Cement in place @ 10:46 HRS.Check floats.Observed slight flow. Pressure floats to 250 PSI for 2 HRS. Bleed&check floats.0 PSI. Floats held. 00:00 02:00 2.00 7,221 PROD1 CASING CIRC P Continue circulate&condition mud with pumps at 4 BPM-430 PSI. Reciprocate casing string in 20 ft increments. Break out and lay down crossover. Back out Top drive. Make up casing hanger and landing joint. Land same on planned depth of 7210'. Make up cement head and crossover. 02:00 07:45 5.75 PROD1 CEMENT CMNT P Batch mix 157 BBLS of cement as t1 per BJ reps.Continue circulate& l'rt �,�1,1 condition mud with pumps at 4 BPM (f -430 PSI. Reciprocate casing string in 20 ft increments.Observed 10% returns in flowline. UP WT-215K, SO WT-123 Held PJSM with crew and BJ reps. Land casing. Pumps off. 07:45 09:00 1.25 PROD1 CEMEN'CMNT P Turn over to BJ. Pump 5 BBLS water to fill lines. Drop bottom plug. Pressure test lines to 3500 PSI. Bleed pressure. Pump 40 BBLS of 10 PPG Mud Push at 4 BPM. Pumps 157 BBLS of 12 PPG cement at 4 BPM.Drop p plug. Page 17 of 18 Time Logs g Date From To Du a Depth S. Depth E. De th Phase Code Subcode T Comment 09:00 12:00 3.00 PROD1 CEMEN"DISP P With rig pump,displace cement with 9.7 PPG brine at 4 BPM. Observed pressure increase catching cement at 2600 strokes, and an increase in pump pressure to 950 PSI indicating good lift. Obtained full returns throughout job,and full reciprocation. UP WT-220K,SO WT-125K.Set hanger at 255 BBL pumped, and oberserved immediate loss of circulation,then bumping plug at 266 BBLS with FCP @ 770 PSI. Increase pressure to 1300 PSI and hold 5 minutes. Bleed pressure and check floats.Observed slight flow. Shut in and pressure to 250 PSI. CIP at 10:46 HRS. Held pressure 2 HRS. Check floats,and they held. Observed 1/4 BBL to fill annulus after observing loss. Note:observed beginning of mud push in the returns when bumped plug. Rig released to completion phase of well at 12:00 Noon. Page 18 of 18 S • ConocoPhillips Time Log & Summary Wei!view Web Reporting Report Well Name: BRU 242-04 Rig Name: DOYON ARCTIC FOX Job Type: INITIAL COMPLETION Rig Accept: 6/26/2012 12:00:00 PM Rig Release: 7/7/2012 11:59:00 PM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06/26/2012 24 hr Summary Breakout&lay down landing joint. Install packoff as per Vetco rep.test same to 5000 PSI. Install 2 7/8"x 5" VBR's in BOP stack and test same to 250/5000 PSI. Record on chart.Clean rig and pits.Transition to completion phase. 12:00 13:00 1.00 0 0 COMPZ WELLPF RURD P Holding 340 PSI on float, bleed down to 250 PSI, Hold for 1/2 hour, continue to rig down Cementers, cleaning pits, bring pack off tools to rig floor. Prepare tools for upcoming ram change. Bleed pressure to zero on float. Floats held. Rig down cement head, lay down landing joint. 13:00 16:00 3.00 0 0 COMPZ WELLPF BOPE P Rig up to set packoff,set with Vetco hand.Test to 5000 PSI for 10 mins. Good. Lay down long bales and casing elevators. Fill 9 5/8"x 7"OA with 3/a barrel mud. 16:00 17:00 1.00 0 0 COMPZ WELLPF BOPE P Pull 7"casing rams and replace with 2 7/8 x 5 VBR's. 17:00 19:00 2.00 0 0 COMPZ WELLPF BOPE P Rig up to test 2 7/8"x 5"VBR's. Test to 250 PSI low 10 mins, 5000 PSI high 10 mins. Rig down test equipment,set wear bushing.6 3/8" ID. 19:00 00:00 5.00 0 0 COMPZ WELLPF RURD P Flush all surface lines to rig with fresh water. Flush kill line,choke line to BOP stack,top drive hose, flushed ram cavities with joint of pipe. Clean rig. Inventory and remove any unnecessary tools and equipment. Clean pit complex. 06/27/2012 Prepare pit system and surface equipment for wellbore cleaning. Flush stack. Pressure wash from crown to the ground. Pump 40 barrels of water through Super choke,manifold,and poor boy degasser into pit#2. 00:00 05:00 5.00 0 0 COMPZ WELLPF RURD P Clean the rig components.Clean shakers, pits, rig floor to cellar. Rig down Sperry shacks and haul to A pad. Flush stack with water while reciprocating pipe through. Pump out cellar box. SIMOPS: Injecting fluid at BRWD. 05:00 07:00 2.00 0 0 COMPZ WELLPF RURD P Replace Driller side link tilt cylinder and install short bails and 4" elevators, repair leaking mix pump. Continue to clean pits. 07:00 10:30 3.50 0 0 COMPZ WELLPF RURD P Continue to prepare pits and surface equipment for wellbore cleaning BHA run, and the caustic soda,safe surf W cleaning pill. Page 1 of 12 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10:30 12:00 1.50 0 0 COMPZ WELLPF SFTY P Safety Meeting with CPAI town leadership.Quarterly safety review. Both crews met simultaneously. 12:00 13:00 1.00 0 0 COMPZ WELLPF SFTY P Safety Meeting with CPAI town leadership.Quarterly safety review. Both crews met simultaneously. 13:00 00:00 11.00 0 0 COMPZ WELLPF RURD P Continue to clean the pits. Pits #4,5,6 completed. Function test mix pump.Good. Inspect drilling line,and drum. Load 35 joints 3%"9.3#L-80 IBT-M tubing,strap,rabbit,move to short side.Clean pipe shed.Work on caustic barrel in welding shop. SIMOPS: Injecting fluid at BRWD. 06/28/2012 Cleaned pits 1,2,3,4,5,6. Mixed and pumped two 150 barrel caustic flush pills through out the surface equipment, pits,degasser,kill and choke lines. Load fresh water in RFR tank. Reset up BJ cement unit. Build filtered fresh water and brine volumes at BRWD. 00:00 06:00 6.00 0 0 COMPZ WELLPF RURD P Continue to clean and prepare the pits, and all rig plumbing.Clean pit #2,drain the gas buster, spot spinner hawks on rig floor.Attempt to pull slack out of the service loop, no go.Mount caustic mixing barrel in pits. SIMOPS:clean the pad,build filtered water down at BRWD. Prepare back haul for barge run. 06:00 12:00 6.00 0 0 COMPZ WELLPF RURD P Continue cleaning pits.Still cleaning pits#3,2,1. Electrician working on caustic barrel mixer motor. Begin to mix the first caustic cleaning pill. Mix 1%drums safe-surf-w, 1 vis cup defoamer, 150 barrels of fresh water from rig tank. Measured at 10 NTU's. Rig up hose from cement line in cellar to cuttings box, rig up cement hose on rig floor to standpipe.Spot citric acid in rockwasher and outside next to cuttings tank.Test rig emergency lights.Good. 12:00 17:30 5.50 0 0 COMPZ WELLPF RURD P Finish cleaning pits#3,2,1. Load and sort MI Swaco BHA components in pipe shed for clean out run. Draw fishing diagrams,get lenghts,OD's, ID,s etc..SIMOPS: Filtering water at BRWD. 17:30 20:30 3.00 0 0 COMPZ WELLPF RURD Finish mixing 1st 180 barrel caustic flush pill in pit#5. Load 5 joints of 4" DP in pipe shed. Place pump from BRWD in spill containment next to RFR tanks. Begin to load filtered fresh water in the RFR tank. 20:30 21:00 0.50 0 0 COMPZ WELLPF RURD P Pump the pill through all surface lines in pits, risers,suctions, equalizers,gun lines. Page 2 of 12 • Time Logs Date From To Dur S.Depth E.Depth Phase-Code Subcode T Comment 21:00 22:00 1.00 0 0 COMPZ WELLPF RURD P Flush lines on rig floor,top drive, flush kill and choke lines,and all lines in choke manifold building,gas buster. Cement line flushed into cuttings tank, all other fluid sent to rock washer. Fluid in rock washer neutralized to 6.5 PH. 22:00 00:00 2.00 0 0 COMPZ WELLPF RURD P Start to batch up caustic wash pill #2. Load 65 barrels of treated wash into vac truck, and send to BRWD. J6/29/2012 Circulate and condition the 2nd caustic wash pill. Pumped job through pits and lines. Disposed of neutralized pill. Flush 200 barrels fresh water in system. Make up Well Bore Cleaning Tools.Trip in hole.Tag float collar on depth.7126'MD.Short trip. Perform 4000 PSI casing test. 00:00 03:00 3.00 0 0 COMPZ WELLPF CIRC P Condition and circulate the 2nd 180 barrel cleaning pill. 1 drum safe surf W. 1 can defoamer,9 sx caustic. Shut in pumps#2,&#3,open bleeders and circulate through bleeders:Open dumps and flush all hopper and gun lines in the pits. Circulate through the hole fill line. Line up to pump#3, pump through entire surface system with annular closed.Go through choke manifold. Rinse bleeder and lower cement line back to cuttings box.Open bag and shut in IBOP,circulate remaining pill through kill line taking returns down flowline. 03:00 09:00 6.00 0 0 COMPZ WELLPF RURD P Dispose of 2nd caustic pill and flush pits with 200 BBLs fresh water. Adjust PH value of fluid in rockwasher and pit system for disposal.Arrive at 6.3 PH and 7.0 PH respectively. Rinse pits with 200 BBLs fresh water.Suck out fluid in pit#5. Rinse all surface equipment, hopper,gun lines. Bring up 3%" handling equipment for WBCT BHA. 09:00 10:30 1.50 0 0 COMPZ WELLPF RURD P Circuclate another 150 barrels of fresh water through out surface equipment, mud lines, hopper and gun lines. 10:30 12:00 1.50 0 60 COMPZ WELLPF PULD P Make up WBCT(Well bore cleaning tools), BHA as per MI Swaco downhole specialists.Torque mill to 8k,connections to 11.5k ft/lbs. Repair blown hose on spinner hawks. 12:00 16:30 4.50 60 7,126 COMPZ WELLPF TRIP P Trip in the hole with WBCT assembly.Tag top of float collar on depth @ 7126'MD. Pick up weight 157k,slack off weight 85k. 16:30 19:00 2.50 7,126 3,500 COMPZ WELLPF TRIP P Trip out of the hole to 3500'MD. 19:00 21:00 2.00 3,500 7,126 COMPZ WELLPF TRIP P Trip back in the hole to 7126'MD. 21:00 22:00 1.00 7,126 7,126 COMPZ WELLPF RURD P Rig up Baker cementers for casing test. Page 3 of 12 • • Time Logs I Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 22:00 22:30 0.50 7,126 7,126 COMPZ WELLPF SFTY P Hold prejob safety meeting in dog house with all parties involved in the 7"casing test. 22:30 00:00 1.50 7,126 7,126 COMPZ WELLPF PRTS P Test surface lines from Baker cement unit to 4000 PSI.Good. Line up to test casing to 4000 PSI for 30 mins.Charted. Held pressure. Lost 0 88 PSI in 30 mins. Held 97.9%of test pressure. Rig down from test. Crew change. 06/30/2012 Test casing to 4k. 30 mins. Pump Safe-T-Pickle job, Reverse circ 440 BBIs fresh water. Perform brine displacement. POOH with the WBCT. 00:00 00:30 0.50 7,126 7,126 COMPZ WELLPF PRTS P Rig down test equipment from casing test. 00:30 01:00 0.50 7,126 7,126 COMPZ WELLPF SFTY P Prejob safety meeting. Pickle the drill pipe and reverse out with 440 barrels filtered fresh water. Discussed fluid movement, high pressure hoses,keep good track of barrels in and out. 01:00 02:00 1.00 7,126 7,126 COMPZ WELLPF CIRC P Load Flo vis pill onto BJ truck from Peak. Load tote of Safe T Pickle onto BJ. 02:00 04:00 2.00 7,126 7,126 COMPZ WELLPFCIRC P Pump Drill pipe pickle job. BJ pumped 20 BBLs Flo-Vis off truck, 10.5 BBLs Safety Pickle out of 3 drums and one tote,displace with 67 BBLs fresh water. Pump @ 1 BPM. 3%returns. ICP=219 PSI. FCP=510 PSI.Take all returns to rock washer. Shut down BJ.Close in TIW valve, shut top pipe rams. Bleed off BJ and wash up to cuttings tank. 04:00 05:00 1.00 7,126 7,126 COMPZ WELLPF RURD P Off load 97 barrels of displaced brine from rock washer into two Peak dirty Vac trucks. Load filtered brine into pits 1,2,3.SIMOPS: Building more filtered brine at BRWD. 05:00 06:30 1.50 7,126 7,126 COMPZ WELLPFCIRC P Reverse circulate filtered fresh water. 7 BPM, 1440 PSI.6592 strokes.436 barrels.Monitored barrels in and barrels out.Measured the NTU's every 50 barrels. Final reading was 50 NTU's.Clean. Stop pumping. Open top pipe rams.Monitor well. Static. 06:30 07:00 0.50 7,126 7,126 COMPZ WELLPF RURD P Rig down cement line, 1502 head pin,TIW valve. Line up to pump down the top drive. Rig down hose from lower cement line to rock washer. BJ Services rigged down and off location. Page 4 of 12 • • Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 07:00 08:30 1.50 7,126 7,126 COMPZ WELLPF CIRC P Haul filtered brine from BRWD to rig with two trucks. Load pits 1,2,3 with 9.8 PPG brine. Build caustic pill in pit#4. Isolate pit#6&load with 130 BBLS filtered fresh water.Place 60 BBLs filtered fresh water into pit#5& mix Safe-Surf-W pill.Spot one drum of Safe-Surf-W next to pit. Rig up to vac truck directly to pump that had 40 BBL Flo Vis pill. Haul off dirty water in outside open top RFR tank and rock washer. Make up top drive to drill string. 08:30 12:00 3.50 7,126 7,126 COMPZ WELLPF RURD P Load pits 1,2,3 with filtered brine.9.8 PPG from BRWD.SIMOPS:Service top drive. Continue to haul off dirty fluid to be injected at BRWD. 12:00 15:30 3.50 7,126 7,126 COMPZ WELLPF RURD P Continue to build filtered brine at BRWD and haul to the rig in preparation for the brine displacement. 15:30 16:00 0.50 7,126 7,126 COMPZ WELLPF SFTY P PJSM in dog house for pumping the clean out pills followed by the brine. All parties in attendance. 16:00 19:30 3.50 7,126 7,126 COMPZ WELLPFCIRC P Pump spacer train as per Mud Engineer,following the Completions Well Plan. Displace well to 9.8 PPG filtered brine,taking returns to the rock washer and the open top RFR 400 BBL tank. Pumped 40 BBLs Caustic pill,40 BBLs Safe Surf-W pill;40 BBLs Flow-Vis pill; 100 BBLs filter floc,displace well with 9.8 brine @ 4.3 BPM. ICP=320 PSI,9%flow, FCP=800 PSI; Reciprocate and rotate @ 80 RPM. 12k TQ. P/U Wt= 120k,S/O Wt=105k, Rot Wt=111 k; 612 barrels pumped,612 barrels returned. 19:30 20:00 0.50 7,126 7,126 COMPZ WELLPF OWFF P Observe well.Static.Change out DS tugger cable in rig floor.SIMOPS: Haul off dirty brine to BRWD, bring in filtered brine to the pits. 20:00 00:00 4.00 7,126 60 COMPZ WELLPF TRIP P Drop 2%"rabbit on wireline. POOH to BHA.Monitor well on trip tank.42 barrels actual displacement.42 barrels calculated. 07/01/2012 Lay down MI Swaco WBCT assembly. Rig up and run cement bond logs under 2000 PSI.Acquire all data. Rig down E-line. Rig up to run Halliburton TCP assembly. Run TCP guns and blanks. Ported fill disk,Champ packer.XO to 4"HT 38 DP. 00:00 00:45 0.75 60 0 COMPZ WELLPF PULD P Lay down Well Bore Cleaning Tools BHA as per MI Swaco. Fill out hot work permit,and take pictures on the rig floor of all tools. Break off mill, and lay down two pieces. Page 5 of 12 . I Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:45 03:00 2.25 0 0 COMPZ WELLPF RURD P Rig down bell nipple/flow riser and install shooting flange nipple on annular. Install new cable in DS tugger.225'. 03:00 03:15 0.25 0 0 COMPZ WELLPF SFTY P Prejob safety meeting with Halliburton wireline crew. Discuss hand and finger safety,the hazards of picking up tools to the rig floor, and the specific pinch points on our rig while wirelining. 03:15 04:30 1.25 0 0 COMPZ WELLPF ELOG P Wireline operations. Hold prejob safety meeting with loggers. Rig up 6 foot 5"extension, hang sheave off of blocks. RIH with logging assembly, pick up grease head and make up line head to tools. Lower grease head and make up to 5"extension with pump in sub. 04:30 05:45 1.25 0 0 COMPZ WELLPF ELOG P Test Halliburton grease head to 1000 PSI,fill hole and lines prior to testing through kill line until good returns are observed at trip tank,shut in return line to trip tank and pressure up to 1000 PSI with MP#3.23 strokes. Good test. Bleed off pressure at pump.Shut HCR kill. 05:45 11:30 5.75 0 0 COMPZ EVALWE ELOG P Wireline logging, Run Cement bond logs.CCUGamma/Monitor hole fill during logging run. 11:30 12:00 0.50 0 0 COMPZ EVALWE ELOG P Wireline logs. Begin 2nd logging pass with pressure. Pressure up to 0 V 1150 PSI. Bled off to 900 in 5 mins. Shut in pump. 12:00 14:00 2.00 0 0 COMPZ EVALWE ELOG P Continue logging.Bring logging pressure up to 2150 PSI. Maintain pressure on well for cement bond log. Initial pressure of 2150 bled off to 540 PSI in 2 hours. 14:00 15:00 1.00 0 0 COMPZ EVALWE ELOG P Rig down logging tools and equipment. 15:00 16:30 1.50 0 0 COMPZ EVALWE NUND P Nipple down shooting flange on annular and nipple up the riser/flow nipple. 16:30 17:00 0.50 0 0 COMPZ PERF SFTY P PJSM with Halliburton TCP crew. Discuss the hazards of perforation guns and hand and finger safety. 17:00 00:00 7.00 0 0 COMPZ PERF PULD Make up the Halliburton TCP assembly. 1491'of guns, comprised of 82'of live guns and 1409'of blanks.7"Champ packer,Jars, RA marker to 4"HT 38 DP. 07/02/2012 TIH W/TCP assembly. Place on drillers depth. Run E-Line correlation. Move guns one foot.2nd correlation run made. R/D E-Line. Fire guns on depth.7113.78'MD. Reverse out 1.5 x's,followed by 2x's BU long circulation. POOH with TCP guns.At the top of the assembly at crew change. Page 6 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase _Code ` Subcode T Comment 00:00 01:30 1.50 0 1,661 COMPZ PERF PULD P Continue to trip in the hole picking up the TCP assembly. Make up the Champ Packer,Jar, 1 stand of 4" DP, RA sub. Up Wt=43k. Dn Wt= 41k. 01:30 07:30 6.00 1,661 7,121 COMPZ PERF TRIP P Trip in the hole with 4"HT 38 DP.45 seconds per stand.Tag up on float collar @ 7121'MD.Slack off 5k, pick up retag,same. L/D top single of stand. Pick up 15'pup joint. Rabbit pup. RIH to 7117'MD, pick up 3 feet to 7114.38'MD,and set slips. Up Wt=165k, Dn Wt=85k. 07:30 08:30 1.00 7,121 7,114 COMPZ PERF ELOG P Rig up Halliburton to correlate, MU valve, HT38 X Otis cross over, , pump in sub. Rig up sheave to top drive, install wireline and pick up top drive to board.Stab grease head. 08:30 10:15 1.75 7,114 7,114 COMPZ PERF ELOG P Wireline logs. RIH with wireline to correlate with gamma ray. Monitor well with hole fill pump. 10:15 10:45 0.50 7,114 7,114 COMPZ PERF ELOG P Complete correlation run. Rig down grease head and hang tools on driller side. Make up top drive, pick up one foot to 7113.78'MD.Set packer. Slack off 10k. Confirm set.set slips break out of top drive, rig up to run E-Line. 10:45 12:00 1.25 7,114 7,114 COMPZ PERF ELOG P Correlate with gamma ray logs 2nd run. Confirm the guns were on depth. 12:00 13:00 1.00 7,114 7,114 COMPZ PERF ELOG P Complete 2nd run to correlate guns on depth. Rig down all Halliburton E-Line tools. 13:00 13:30 0.50 7,114 7,114 COMPZ PERF PERF P Prejob safety meeting on perforation and circulation plan forward following the perfs. I 13:30 16:00 2.50 7,114 7,114 COMPZ PERF PERF P Perforation. Halliburton dropped bar @ 1325 hrs. Confirm guns fired. Monitor well. Open by pass and reverse circulate 90 barrels @ 4.3 BPM. ICP=500 PSI 50%choke, FCP=440 PSI.Open choke to 75%. 4.3 BPM 350 PSI. Monitor well 15 mins.static.Circulate normal flow path @ 4.3 BPM 1.5 x's bottoms up. FCP=285 PSI. 16:00 16:30 0.50 7,114 7,114 COMPZ PERF OWFF P Observe well for flow or losses. Static. 16:30 21:30 5.00 7,114 7,114 COMPZ PERF TRIP P Trip out of the hole at 2 mins per stand. Monitor the hole on the trip tank. Good displacement.Well static. 21:30 22:00 0.50 7,114 7,114 COMPZ PERF OWFF P Observe well for flow.Some bubbling, break out gas, but no flow. Finally died off after 30 mins. 22:00 22:30 0.50 7,114 1,661 COMPZ PERF SFTY P Prejob safety meeting. Lay down guns. Repair glycol leak on DW. Page 7 of 12 • 111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 1,661 1,601 COMPZ PERF PULD P Make up 4 5/8"Stub ACME Box XO to 3'/z'IF x 3'/z"IF ported sub to bottom of stand for well control. Lay down Champ packer, and two joints of 2 7/8"EUE tubing. 07/03/2012 Lay down 68 Millenium Halliburton blanks and guns. Run BHA#3. MI Swaco Well Bore Clean Out tools, deburring run. POOH to 1344'MD.Crew change. 00:00 06:30 6.50 1,601 0 COMPZ PERF PULD P Continue to lay down the Halliburton Millenium perforation assembly. Once out of the hole.Monitor well. Static. 06:30 07:15 0.75 0 0 COMPZ PERF PULD P Clean and clear rig floor. Remove perforation circ XO from bottom of stand. 07:15 07:30 0.25 0 0 COMPZ PERF SFTY P Prejob safety meeting with Mi Swaco downhole specialist. Picking up clean out tools. 07:30 09:00 1.50 0 82 COMPZ PERF PULD P Make up WBCT(Well bore cleaning tools). BHA#3. Mill/Magnostar/Ridge back burr mill/Casing scraper/ Magnostar/Well Patroler. 09:00 12:00 3.00 82 3,857 COMPZ PERF TRIP P TIH with BHA#3 to top of the perfs. 3857'MD. 12:00 13:30 1.50 3,857 5,615 COMPZ WELLPF TRIP P TIH to top of the perforations @ 5615' MD. 13:30 16:30 3.00 5,615 7,123 COMPZ WELLPF REAM P Reaming the perforations as per MI REP.3 BPM,200 PSI, 5%flow,60 RPM,7K TQ,Wash down and tag top of the float collar @ 7123'MD. 16:30 18:00 1.50 7,123 5,555 COMPZ WELLPF TRIP P Trip out of the hole to 5555'MD.2 mins.per stand. 7.2 BBLs calc.6.25 BBLs actual. 18:00 19:30 1.50 5,555 5,555 COMPZ WELLPF CIRC P Condition and circulate the brine. 1 bottoms up @ 3 BPM,200 PSI, Increase flow rate to 5 BPM, 570 PSI.The NTU's started out @ 350 and came down to 44.Shut down pumps. 19:30 20:00 0.50 5,555 5,555 COMPZ WELLPF OWFF P Monitor the well for flow. Static. 20:00 22:30 2.50 5,555 1,594 COMPZ WELLPF TRIP P Drop 2.375"rabbit on wireline. POOH to 1594.Actual displacement=22 BBLS. Calculated 23 BBLS. 22:30 22:45 0.25 1,594 1,594 COMPZ WELLPF OWFF P Observe well for flow.Static. 22:45 23:00 0.25 1,594 1,594 COMPZ WELLPF SFTY P Prejob on laying down singles. 23:00 00:00 1.00 1,594 1,344 COMPZ WELLPF TRIP P Lay down singles into the pipe shed. 8 joints. 07/04/2012 LID 4"DP. L/D MI Swaco tools. Rig up and run Lower Completion to setting depth Rig up E-Line. 00:00 02:30 2.50 1,344 82 COMPZ WELLPF TRIP P Trip. POOH. Lay down drill pipe in pipeshed to BHA#3.Good hole fill. 02:30 02:45 0.25 82 82 COMPZ WELLPF OWFF P Observe well. Prejob safety meeting with MI Swaco downhole hand. 02:45 03:45 1.00 82 0 COMPZ WELLPF PULD P Lay down BHA#3.Take pictures, estimate 70 lbs of metal retrieved. Page 8 of 12 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:45 05:30 1.75 0 0 COMPZ WELLPF SFTY P PIR Near Miss Incident review with crews. Prejob meeting about running 3W IBTM completion. 05:30 07:00 1.50 0 0 COMPZ RPCOM RCST P Rig up to run 3%"9.3#, L-80, IBT-M Lower Completion. Rig down rig tongs, install 3%2'elevators,caliper check.Good.Arrange completion jewelry in running order. Pick up Weatherford double stack casing tongs. Rig up power unit and hydraulic hoses. 07:00 07:45 0.75 0 0 COMPZ RPCOM SFTY P Prejob safety meeting: Running lower completion. 07:45 12:00 4.25 0 394 COMPZ RPCOM RCST P Run 3'/%"9.3#, L-80, IBT-M Lower Completion as per running order. Torque connections to the mark. Check for seal rings. Up Wt=30k, Dn Wt=30k. 12:00 15:30 3.50 394 979 COMPZ RPCOM RCST P Run Lower Completion.3%"9.3#, L-80, IBT-M tubing.and jewelry as per detail. Ran 5 packers,4 frac sleeves,4 flow screens,one X nipple. 15:30 16:30 1.00 979 979 COMPZ RPCOM RURD P PJSM. Rig down Weatherford, rig up rig tongs for tripping in the hole. 16:30 17:00 0.50 979 1,075 COMPZ RPCOM RURD P P/U 1st stand of drill pipe and install RA sub. 17:00 17:30 0.50 1,075 1,075 COMPZ RPCOM SFTY P Renact Near Miss Incident in Pipe shed. Safety stand down. 17:30 22:30 5.00 1,075 6,453 COMPZ RPCOM RUNL P Run lower completion on drill pipe. One stand per minute. Set slips in tension.Good displacement. Calculated=Actual=31.4 BBLs. 22:30 23:00 0.50 6,453 6,453 COMPZ RPCOM SFTY P Prejob safety meeting with the Halliburton E-Line crew. Discussed pipe shed safety,keeping un-needed people out of harms way. 23:00 00:00 1.00 6,453 6,453 COMPZ RPCOM RURD P Rig up wireline tools and equipment for correlation with RA marker sub prior to setting the packers. 07/05/2012 Run Halliburton RA correlation E-Line logs. Pick up long bales and set lower completion on depth @ 6445.12' MD. Set the packers. POOH laying down all the drill pipe. Prepare to run the Upper Completion.Stage tools. Camco reels, 182 joints of 4%"12.6#L-80, IBTM. 00:00 00:15 0.25 6,453 6,453 COMPZ RPCOM SFTY P PreJob safety meeting with Halliburton Wireline crew. 00:15 01:00 0.75 6,453 6,453 COMPZ RPCOM ELOG P Rig up Halliburton. Pressure control equipment. 01:00 02:00 1.00 6,453 6,453 COMPZ RPCOM PRTS P R/U to pressure test Halliburton PCE against TIW.Test to 3500 PSI. Good. 02:00 03:30 1.50 6,453 6,453 COMPZ RPCOM ELOG P Run in the hole to confirm packer set depth.Verify RA marker @ 5407' MD. 03:30 05:00 1.50 6,453 6,453 COMPZ RPCOM RURD P Rig down Halliburton E-Line pressure control equipment. Page 9 of 12 • Time Logs Date From To ! Dur S.Depth E. Depth Phase Code Subcode T Comment 05:00 07:30 2.50 6,453 6,453 COMPZ RPCOM RURD P Rig up to set packers. Rig down short bales, rig up long bales,make up pump in sub, Halliburton valve and swing to TIW in stump. Make up cement hose to swing,and line up Baker Cement truck to pump down the drill pipe. 07:30 08:45 1.25 6,453 6,453 COMPZ RPCOM PRTS P Hold Prejob safety meeting with Baker Cementers. Feed cement truck 9.8 PPG brine from rig pits for testing and setting packers.Send 10 barrels. Baker break circulation,shut in TIW valve and test lines to 4000 PSI, set lower completion on depth (6445.12'MD)drop 1"ball and let fall 20 mins. 08:45 09:45 1.00 6,453 6,453 COMPZ RPCOM PACK P Baker Cement truck set the 5 Premier Packers. Pressure up to 500 PSI to confirm ball placement. Pressure up to 2500 PSI. 5 mins. Pressure up to 4000 PSI. 5 rains. Bleed off.overpull 20k. Rig pressured up annulus to 1000 PSI.5 mins. Set down 20k pressure up to 3000 PSI and unsting from running tool. 09:45 10:00 0.25 6,453 6,453 COMPZ RPCOM OWFF P Observe well for flow.Static. 10:00 12:00 2.00 6,453 6,453 COMPZ RPCOM RURD P Rig down after setting packers and releasing running tool. Lay down head pin,and TIW. Rig down long bales, rig up short bales. Lay down one single.and RIH with TIW,break off head pin and TIW. 12:00 13:30 1.50 6,453 4,404 COMPZ RPCOM TRIP P Held Pretour meeting and discussed laying down drill pipe. Lay down DP to 4404'MD 13:30 14:00 0.50 4,404 4,404 COMPZ RPCOM OWFF P Observe wellbore.Static. 14:00 18:30 4.50 4,404 506 COMPZ RPCOM TRIP P Continue to lay down singles into the pipeshed. 18:30 19:00 0.50 506 506 COMPZ RPCOM OWFF P Observe wellbore.Static. 19:00 20:00 1.00 506 0 COMPZ RPCOM TRIP P Continue to lay down singles into the pipeshed. 20:00 20:30 0.50 0 0 COMPZ RPCOM PULD P Break down Baker running tool,and lay down into pipe shed. 20:30 21:00 0.50 0 0 COMPZ RPCOM RURD P Pull wear bushing. 21:00 00:00 3.00 0 0 COMPZ RPCOM RURD P Prepare for Upper Completion. Lay down rig tongs,slips,wear ring running tool, install 4%"tubing elevators, make up XO 4%IBTM to 4"HT 38 to floor safety valve. Load and strap 4%"L-80 IBT-M, 12.6# tubing in the pipe shed.Stage Schlumberger SSSV and chemical injection reels next to rig, rig up. Strap and measure completion jewelry. Page 10 of 12 • Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 07/06/2012 24 hr Summary Run 176 joints of 4%"12.6#, IBTM, L-80 tubing.Space out 3 feet up from fully located. Ran 179 cannon clamps. 00:00 03:00 3.00 0 0 COMPZ RPCOM RURD P Strap and tally 182 joints of 4'/z' tubing.Spot the Schlumberger spooling units. Held a PJSM with all hands involved, rig up sheaves @ derrick board. 03:00 04:30 1.50 0 0 COMPZ RPCOM RURD P Continue to strap and tally tubing in pipe shed. Finalize tally. 182 jts in shed.2 outside. 10 space out pups. 04:30 05:00 0.50 0 0 COMPZ RPCOM SFTY P Hold PJSM in doghouse with all service hands involved in running tubing.Weatherford.Schlumberger. Baker. 05:00 12:00 7.00 0 2,276 COMPZ RPCOM RCST P Run 4'/2"12.6#, L-80, IBT-M, Upper Completion. Run Seal Assembly/ Locator sub/XN Nipple/GLM with DCK2 shear pinned @ 2500 PSI. Run tubing to 2276'MD. 12:00 21:30 9.50 2,276 5,501 COMPZ RPCOM RCST P Run 4'%"12.6#, L-80, IBT-M, Upper Completion. Placing a cannon clamp on every joint. Run a total of 158 jts to the SSSV. Rabbit the SSSV with the ball and rod. Install SLB 1/4"line and begin to run both lines to the hanger.Wash down Jt 178 to see the mule shoe enter the seal assembly.Tag up one foot high to calculated. Fully located @ 5504.22'. Mark pipe. 15 feet in on joint 178. Pick back up to circulate. 21:30 21:45 0.25 5,501 5,501 COMPZ RPCOM SFTY P Prejob safety meeting with crews about displacing inhibited brine. 21:45 23:00 1.25 5,501 5,465 COMPZ RPCOM CIRC P Circulate @ 4 BPM. 100 BBLS inhibited brine,chased with 83 barrels 9.8 filtered brine. 23:00 00:00 1.00 5,465 5,501 COMPZ RPCOM HOSO P Lay down jts. 178/177/176. Pick up two pups. 9.87',9.89'. P/U Jt 176. Make up hange and landing joint. Land 2.78'out from fully located. 07/07/2012 Make up hanger.Test the annulus to 3000 PSI,test the tubing to 3000 PSI.Shear the DCK2 valve. ND BOPE. NU Dry hole tree. 00:00 01:30 1.50 5,501 5,501 COMPZ RPCOM RCST P Make up Hanger and terminate control line and chemical injection line. Lay down tubing tongs,pull bushings,wash stack. 01:30 03:15 1.75 5,501 5,501 COMPZ RPCOM RCST P Land hanger Up Wt=106k, Dn Wt=62k, Run in upper lock down screws.Test hanger seals to 500 PSI 10 mins. 5000 PSI 10 mins. 03:15 04:00 0.75 0 0 COMPZ RPCOM PRTS P Lay down landing joint,set TWC, install landing joint, make up XO's, Lo Torque valve,test equipment. 04:00 04:15 0.25 0 0 COMPZ RPCOM PRTS P Test connections on XO's,top of TWC to 3000 PSI, 5 mins.charted. Page 11 of 12 f • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:15 04:30 0.25 0 0 COMPZ RPCOM RURD P LD landing jt. Pull TWC. MU landing jt. RU test equipment. 04:30 05:00 0.50 0 0 COMPZ RPCOM PRTS P Pressure annulus to 1500 psi.OK. Pressure tbg to 3000 psi for 10 min. OK, 05:00 05:15 0.25 0 0 COMPZ RPCOM OTHR P Pressure tbg to 4900 psi to shear ball seat in tbg tail. 05:15 05:30 0.25 0 0 COMPZ RPCOM OWFF P Monitor well for 15 min.Static. 05:30 06:00 0.50 0 0 COMPZ RPCOM PRTS P Drop ball and rod. Let fall for 15 min. Pressure tbg to 1500 psi to comfirm ball seat. Bleed off pressure.Open to tbg to flowline. 06:00 06:30 0.50 0 0 COMPZ RPCOM OTHR P Pressure annulus to 3000 psi to shear DCK-2 valve. 06:30 07:30 1.00 0 0 COMPZ RPCOM OTHR P Suck out BOP stack. Install BPV. MU landing jt. 07:30 08:00 0.50 0 0 COMPZ RPCOM PRTS P Pressure annulus to 3000 psi for 30 min.to test BPV in direction of flow. 08:00 10:00 2.00 0 0 COMPZ RPCOM OTHR P PJSM. Flush choke manifold,kill line and stack with fresh water. Blow down choke line, kill line, mud line and pumps. 10:00 12:00 2.00 0 0 COMPZ WHDBO NUND P PJSM. ND flow line and riser.Choke line, prepare for rig move. 12:00 19:00 7.00 0 0 COMPZ WHDBO NUND P Nipple down BOPE. Empty pit system and prepare for rig move. Vac out containments, begin to remove Handi_berm around rig. Crane removed centrifuge house, auger from pits, poor boy degasser tour: Load out rock washer and cuttings tank, mud engineer shack,5 rig mats and BOPE.3 misc. loads, mud products, rental koomey, MI filtration pump skid. 19:00 00:00 5.00 0 0 COMPZ Assist Vetco/GE Well head hand nipple up dry hole tree.Orient tree as per Company Man. Prepare top drive for rig down. House keeping, and store egjuipment away for move. Prepare pipe shed for load out.Clean suction screens,and tubes on mud pumps. Rig down surface lines. Remove the remaining Handi-Berm, after sucking out all the rain water with the Peak vac truck. Empty the cellar box out.30 BBLs. Page 12 of 12 BRU 242-04 Well Work Summary • DATE SUMMARY 7/11/12 Remove production tree and set lwr frac tree. Lubricate out BPV, set 2-way check. PIT Iwr frac tree to 10k#. 7/12/12 Install upper frac tree assembly. Test to 10k#for 10 mins; held solid. Install adapter and otis connection.lnstall upper frac tree assembly. Firm up site control. 7/13/12 Rig up slickline, pull sleeve, ball & rod, RHC plug body. Swap SOV w/dmy. Lay down pit liner and begin spotting frac tanks. Meet with PEAK crew for pre job, establish CPAI expectations. Only 1 vac truck avail to haul water so move driver/roust to night. 7/14/12 Set remaining frac tanks and manifold together. Begin hauling filtered fresh water to tanks. Remove plywood cellar cover and have PEAK fab metal grating cover. 7/15/12 Continue hauling FW. Building dikes. Baker frac crew on location; conduct pre job safety meeting with crew, explain CPAI expectations. Delays with barges continue to cause issues. 7/16/12 Spot frac equipment, begin rigging hardline. Haul remaining FW, KCL to site. Still waiting on remaining Baker equipment to arrive by barge; playing catch-up from earlier weather delays. 7/17/12 Baker frac crew continued spotting equipment and rigging hardline (hardline 90%complete). 1 �►� Completed mixing 4/6 frac tanks with KCI. Loaded 56,100#proppant into Sand King, and 1 hauled 56,100#to location for loading tomorrow. PEAK roustabouts laid felt/herculite. S(/'� Backside combi pump on location and spotted. Barricaded and other safe zone measures implemented for crane operations. Handy-Berm completed standing up dike walls. Vetco hand fixed nipple issue at hydraulic tree valve. 7/17/12 Baker frac crew continued spotting/rigging-up equipment; completed rigging-up treating iron to the wellhead and flowback to tanks. Completed mixing 6/6 frac tanks with KCI. Loaded 190,200#proppant into Sand King, and hauled another flat-bed of super-sacks to location for loading after stage one. Improved Safe Work Zone measures as rig-up and site plan evolved. Tested all chemical additive pumps. Spotted up and rigged in the gel transport. Started and PM'd all equipment. Topped-off all equipment for frac. LRS heated tanks to 80- deg F, and should be done tonight. 7/18/12 Performed DFIT test and analyzed pressure decline. Determined reservoir parameters and optimized final fracture treatment design. Executed fracture stimulation treatment in the I-sand interval, pumping 1380-total-bbls of T"5A(39 linear and crosslink gel (25# Lightning 2500), and 101,422-total-lbs of 20-40 ZG Polar Prop resin coated proppant, continually increasing sand concentration from 1.0-7.1 PPA. [BHISIP 5200-psi]. (Will attach detailed Job Log and BHI Pump Report upon availibility.) 7/19/12 Conducted D&W Safety Stand Down at Cottonwood Shop with CPAI, Baker Hughes, Pollard Wireline, LRS, and Vetco Gray. Deployed 1.3"OD ball; circulated ball to seat. Shifted seat and performed Stage 2 DFIT test. Analyzed pressure decline to optimize final fracture treatment design. Re-loaded tanks with water and mixed to 6% KCI. Reloaded Sand Chief with 200,000#proppant. LRS heated tanks to 80-deg F. Serviced all equipment and organized site for 6:30am PJSM to start down hole with Stage 2 main frac. 7/20/12 Pumped the Stage 2 fracturing treatment. Fracced the H-sand interval, pumping 998-total- bbls of linear and crosslink gel (20#Lightning 2500), and 103,000-total-lbs of 20-40 ZG Polar Prop resin coated proppant, continually increasing sand concentration from 1.0-6.1 PPA. Screened out 63-bbl into the 93-bbl displacement. Performed slickline 1.7" LIB run to 5494' SLM and got back smudge indications of an apparent shoulder contact. Performed slickline 1.7" spear run to 5515' SLM and again set down at 5515' SLM. Currently running slickline 1.5"OD slinky tool. 7/21/12 Pumped the Stage 2 fracturing treatment. Fracced the H-sand interval, pu • g 998-total- bbls of linear and crosslink g Lightning 2500), and 103,000-total-lbs -40 ZG Polar Cyr Prop resin coated proppant, c nually increasing sand concentration from . -6.1 PPA. H 'NO Screened out 63-bbl into the 93-bbl displacement. Performed slickline 1.7" LIB run to 5494' SLM and got back smudge indications of an apparent shoulder contact. Performed slickline 1.25"spear run and set down at 5515' SLM. Performed slickline 1.5" OD slinky tool and set down first at 5494', then jarred once and dropped to 5515'. Performed slickline 1.5"sample bailer run and set down at 5515' SLM; saw quick WHP increase from 0-to 250-psi as slickline tool pulled heavy off tag depth, then could not get back down passed 5490'. Acquired full bailer packed with proppant when back at surface. Prepped for CT operations and notified State of intent to test BOPE on 22-July-12. 7/22/12 Rigged up Baker coiled tubing unit and tested BOPE (AOGCC Lou Grimaldi waived witness 12:20pm). Attempted CT FCO but aborted run due to plugging Baker Vortex Nozzle. Pulled out of hole, pumped CT volume, and made up standard jet swirl nozzle. Ran in hole to clean out but encountered pump/fluid-transfer issues with CT just about at sand top 5515' SLM. Scheduled 04:30am restart for FCO in order to revise rig-up with remaining time available tonight. 7/23/12 Performed coiled-tubing fill clean out to 5,607' CTMD, approximately 30' below the Halliburton 3-1/2" Frac door(with 2.05" Ball seat)at 5,577' MD, pumping 1.7-2.0 bpm using 6% KCI water and 25#Lightning 2500 gel pills while penetrating frac sand. Pumped from 5,607'to surface maintaining 2.0-bpm; unable to cleanly acquire sample from returns stream due to weir-tank configuration. Deployed slickline 3-1/2" GS to pull frac sleeve from BP6i SCSSSV, but unable to pass through CT BOPE stack. Inspected BOPE and found metal shavings in stack. Also C/ found shavings in the sump below the injector head and around stuffing box. Found a chunk of stainless looking metal, with some broken edges and some machined edges, that closely resembles a broken-off piece of injector skate bearing race. To one side, the metal chunk had a sharp wedge very close in width to a large portion of the metal shavings. Ran a 3.0" rare-earth magnet and removed all the metal down to the frac sleeve. Pulled the frac sleeve with 4.5" GS, and again fished metal shavings with 3.0"and 2.0" rare-earth magnets to 5494' SLM. Unable to fall passed 5494'with magnet, and magnet stopped bringing back metal. Rar 7/24/12 Performed coiled tubing unit maintenance: removed chains; replaced skates and bearings; installed chains, lifting frame and gooseneck. Stabbed pipe and installed new electronic depth encoder at the injector. Repacked stuffing box and prepped unit and site to RIH first thing in the morning. Inspected the skate bearings from the injector and they all looked perfectly fine; no damage found to any of the bearings, skates, or chains. Replaced bearings just as a precautionary measure. Hauled out all returns fluids and manifested for disposal. Continued hauling out shipping waste from proppant and KCI products for disposal or transport. 7/25/12 Performed coiled tubing fill clean-out down to Halliburton 3-1/2"frac door at 5,577' pumping 2- bpm with 6% KCI water and 20#x-link gel. Pulled 2.05" Ball Seat with 3-1/2" hydraulic GS fishing tool on coiled tubing. Performed slickline LIB run; got back distinct impression of frac sand at 5545', plus a couple of scratches that could be indicative of remnant metal shavings. Performed slickline magnet runs(4 total)to confirm that no metal shavings remain in the well above sand top; (1st magnet came back covered with shavings; 2nd half-covered; 3rd quarter; 4th two slivers; 5th clean). Hauled out CT FCO returns, and hauled in water for frac tanks. Continued hauling out shipping waste from proppant and KCI products for disposal or transport. Transferred LN2 from transport that came in on barge to combi unit for future N2 lift. Lined up for FCO in the A.M. Sand top is at 5545' RKB. 7/26/12 Performed coiled tubing fill clean-out down to second Halliburton 3-1/2"frac door ball seat at 5,736' pumping 2-bpm with 6% KCI water. Attempted to pull 1.80" ball seat with hydraulic GS on CT during cleanout; saw overpull at surface but no fish once back at surface. Ran slickline 3-1/2"GS baited with 2-1/2"JD to tag at 5608' SLM. Ran in with slickline 2.5" LIB; set down on fish but also showed proppant and metal shaving imprint. Ran in slickline 2.5" magnet twice; a few metal shavings returned. Laid down slickline and rigged up coiled tubing. Ran in 3-1/2" hydraulic GS and cleaned down to 5608'; pushed fish to 5737' and pulled wiper trip to surface. Cleaned hole again and attempted to latch fish, but unable to recover the ball seat. 7/27/12 Attempted fishing ball seat with slickline. Went in with 2.5" magnet and rec red two small metal pieces from 5611'. Rarith 1.5"drive-down balier to 5748'and c OH with no sample. Ran 2.7"gauge ring oubleshoot inability to pass 5611'with larg r tools; tools stopped falling at 5611' but able to fall to 5748' after one jar lick. Ran 3-1/2" GS to 5748'and jarred down but unable to latch fish. No visible work on the brass pin; redressed tool with steel pin and RIH. Hit 20 jar licks down; still no latch. Ran magnet again and recovered two small pieces. Ran 2" pump bailer and made 5748 to 5750'; came back packed with frac sand. Ran 2"drive-down bailer 5750-5753'; came back packed with frac sand. Ran 2"drive- down bailer 5748-5750'; came back packed with frac sand. Rigged up coiled tubing and cleaned out above ball seat pumping 2.0-bpm 6%KCI water through 2.0"down and side-swirl jet nozzle. Maintained minimum 600-psi WHP throughout clean-out and left 880-psi WHP on well rigging down CT. Rigged up slickline and PTd lubricator to 1200-psi. Bled lubricator to 7/28/12 Attempted fishing ball seat with slickline. Ran 3-1/2" GS to 5740' and jarred down but unable ,/ to latch fish. Bailed proppant with 2" pump bailer and made 5748 to 5750'; came back packed with frac sand. Ran 2" pump and drive-down bailers; came back packed with frac sand. Rigged up coiled tubing and cleaned out through 1.8"ball seat pumping 2.0-bpm 6%KCI water through 1.5"stinger with down and side-swirl jet nozzle. Ran in with 3-1/2" hydraulic GS on coil. No fish. 7/29/12 Attempted fishing ball seat with slickline after CT cleanout. Ran 3-1/2"GS to 5766'and spanged down but unable to latch fish. Lost power in slickline unit; found PTO coupling spline had been stripped and replaced coupling. Ran 2" pump bailer and worked to 5766'; came back minimal amount of frac sand. Ran 1.5"drive-down bailer to reach inside GS fishing neck; came back with minimal with frac sand. Ran 3-1/2"GS to 5766'and spanged down but unable to latch fish. Rigged up coiled tubing and ran 3-1/2" hydraulic GS on coil; able to latch fish, but unable to dislodge it with three 30k#straight pulls and three 2-1/8"x 3'jar licks. After three CT runs, unable again to latch up. Inspected GS pulling tool and looks fine; cut CT and performed injector maintenance. Rigging up slickline for magnet and LIB run, and getting longer jars and accelerators to location. 7/30/12 Ran slickline 2.5" LIB run after CT fishing attempts became unable to again latch fish. LIB showed few metal marks but not indicative of the fishing neck. LIB did, however, come back with thick resin-like deposit heavy along one side. Ran brushes on slickline and got back heavy with same resin-like substance, along with two small slips of plastic-bag like pieces. Ran bailers and made three feet; came back empty but had same substance on the outside of toolstring. Also got back indications on bottom of bailer ball-seat fishing neck. Ran 3-1/2" GR on slickline and latched fish. Jarred up six times and sheared off. Ran 3-1/2"GS and latched with one lick down. Jarred up 26 times but unable to dislodge ball seat. Sheared down off of fish and rigged up CT. Picked up two sections of lubricator, and picked up the Weatherford fishing tools delivered today (2-1/8" MHA, 7' up-jars, and 8' intensifier). Latched fish and straight pulled 35k#with one jar lick. Retrieved the 1.8" ball seat from 5,736'. Ran It back in hole with nozzle on 1-1/4"stinger to clean down to/through 1.55" ball seat at 6,142'. 7/31/12 Rigged S/L and tagged top of fill with bailer @ 5977' RKB, —165' above H sand ball seat. Began bailing, alternating between pump/drive-down bailer(waiting for coil crew to come on shift). Rig up CTU, perform weekly BOPE test(test witness waived by Jim Regg @15:45). Perform cleanout to top of ball seat @ 6142'with fishing BHA, 1-1/4"stinger. Circ'd @ 2.6 bpm with aid of friction reducer. 8/1/12 Made up fishing BHA/3-1/2"GS and attempted to fish seat. Made 3 attempts to latch; no good, GS stuck in release position. Rig down CTU (crew"houred out")and rig up slickline to bail/fish. Ran in with bailer, recovered no sand but had metal marks on tools, ran GR, unable to latch. Made brush run and cleaned up FN profile; reattempted with GR. Latched fish (after pressuring up tubing), sheared off and ran back in hole with GS. Recovered ball seat. Rigged up CTU and cleaned out w/ 1-1/4"stinger to top of lower ball seat. Made attempt at to fish seat, tagged fill —10 high. Ran back in hole for another cleanout run. 8/2/12 Finish 2nd cleanut run to ball seat @ 6251'. Rigged down coil, rigged up S/ d tagged seat with pump bailer(no solids re ed in bailer, metal marks on bottom). R hole with BLB and cleaned up fishing neck. in with 3-1/2 GR, sheared tool after secon ick. Ran back in with GS, latched and began beating; no jars, spangs only. After 45 mins of beating, attempt to shear off; can't get off seat. Let wire rest, bring on pump @ min. rate (well taking fluid) and flush tbg/sleeve. Resume working wire,jars firing now. Pop free, POOH and cut wire, rebuild jars, etc. Run back in hole with bailer, seat appears clean. Run in hole with GS, latch up and begin working up hole getting stuck in each frac door on way out. At surface with ball seat; lay down S/L for the night. 8/3/12 Locate sleeve 6251'with shifting tool for correlation. Flag wire. Make up HES 14, fra, DPU/adapter/Baker composite bridge plug and set @ 6269' RKB. Test tubing to 5000 psi, monitor for 10 mins; good. Shift sliding sleeve open @ 6142', install frac sleeve. Pump 25 (Air bbls 6% KCL; perform pressure analysis. Performed DFIT for pressure analysis. Pumped Stage 3 fracturi • -- ••-• - •• •- ••- - --•: •- - :I with linear and crosslink gel / (20#Lightning 2500)and 88,373 total lbs of 20-40 ZG Polar Prop resin coated proppant(88% r/ of design), increasing sand concentration from 1.0-6.0 PPA through treatment. Flushed to completion. 8/4/12 Prep'ped for Stage 4 frac. Serviced frac tree, pulled frac sleeve, tagged fill @ 6191' cor RKB, closed sliding sleeve @ 6142'. Pressure tested tubing to 5000 psi; solid test. Opened sliding f i rte" I sleeve @ 5736', in the process opening sleeve @ 5577'. Close sleeve @ 5577'. Re-set frac �,� sleeve. Performed DFIT for pressure analysis. Pumped Stage 4 fracturing treatment frac'ing ° the lower G-sand interval through sleeve @ 5736'with 1,253 bbls linear and crosslink gel (20#Lightning 2500)and_1Q1,472total lbs of 20-40 ZG Polar F}rop resin coated proppant (101%of design), increasing sand concentration from 1.0-6.0 PPA through treatment. Flushed to completion. 8/5/12 Pulled frac sleeve @ 539'. Tagged top of fill @ 6098' KB. Closed sleeve @ 5736'; P!T'd tubing to 5000 psi; good. Opened sleeve @ 5577'. Reset Frac sleeve. Performed DFIT. Pumped Stage 5 fracturing treatment frac'ing the upper G-sand interval through sleeve @ 5577'with 1,695 bbls linear and crosslink gel (20# Lightning 2500)and 105,637 total lbs of 20- 40 ZG Polar Prop resin coated proppant(105% of design), increasing sand concentration from 1.0-6.0 PPA through treatment. Flushed to completion. Rigged up slickline and pulled frac sleeve, tagged fill @ 6007' RKB, and closed sleeve @5577'. 8/6/12 Rigged up coiled tubing and cleaned down to top of composite plug @ 6269'. Made up 2-1/8" WF milling BHA w/BI jars&5-bladed junk mill and attempted to mill out composite plug (tagged @ 6254' CTM). Had difficulties, seem to be sitting and spinning. Pulled out of hole to inspect tools, buttons on bottom face of mill chipped, metal debris stuck in channels on outside of mill. Lay down for night. 8/7/12 Rigged slickline and RIH with magnet; set down @ 5610' KB. Pull out of hole, debris suspect from composite on magnet up to 1/2". Repeat run, same results. Reconfigure tools, add centralizer to"hop"the lip from jewelry and RIH to top of plug. Recover more metal debris, pieces up to—1"x 1/2", different type of metal, soft/malleable. Continue with magnet runs until no large pieces of metal recovered. Lay down slickline. Rig CTU and perform weekly BOP test(test witness waived by Jim Regg via email). 8/8/12 Milled out composite bridge plug hung up at 6250' CTM and chase out of tubing into 7"with WF 2-18" milling assembly/2.73" 5-biased junk mill. Remove milling BHA, install 1-11/16 dimple-on connector, checks, 1.75" nozzle. Clean fill to TD, making wash passes across sleeves to eliminate composite/metal debris. RD CTU. 8/9/12 Tag fill, open select-a-flow sleeves, set PXN plug in XN profile and catcher, test plug, pull DMV in GLM and blow down well with N2. 8/10/12 Changeout Frac Tree with Production Tree, prepare for well test equipment rig up 8/11/12 Prepare pad for well test equipment rig-up. 8/12/12 Mobilize well test equipment to pad 8/13/12 Spot well test equipment and rig up lines. 8/14/12 Continue to rig up hard lines and ESD system 8/15/12 Complete rig up of well test equipment and pressure test. 8/16/12 Change wellhead hook up. ,,,, 8/17/12 All equipment in place and pressure tested. Waiting on SSV panel installation by CPAI. (Cote 8/18/12 Opened well at 15:00 hrs 8-18-12. Bled off gas cap, recovering water 8/19/12 Continue to flow well-water coming back- no sand -no gas 8/20/12 Continue to flow well-water coming back-no sand -no gas 8/21/12 Continue to flow well- no sand -no gas-by pass sep at 19:00 8/22/12 Continue to flow well- no sand -no gas • 8/23/12 Continue to flow well- no saro gas 8/24/12 Continue to flow well- no san no gas 8/25/12 Continue to flow well- no sand - no gas 8/26/12 Continue to flow well- no sand - no gas 8/27/12 Continue to flow well- no sand - no gas 8/28/12 Continue to flow well-no sand, trace of gas 9,000 ppm salinity 8/29/12 Continue to flow well-no sand, trace of gas-9,000 ppm salinity 8/30/12 17:30 Begin gas lifting well w/N2. 19:30 stabilize lift rate at 432 scfm. 8/31/12 00:00-16.8 mscfd net, 753 BWPD with 432 scfm lift gas. 00:30 Increase lift rate to 576 scfm. 13:00-297.7 mscfd net, 972 BWPD with 576 scfm lift rate. 17:00 close lower G production sleeve. 9/1/12 03:00 -136.8 mscfd net, 1123 BWPD with 575 lift rate. 03:30, Increase lift rate to 720 scfm. 06:00 Increase lift rate to 863 scfm. 13:30, -1.13 mscfd net, 864 BWPD with 864 scfm lift rate. 14:00 shut-in well. 9/2/12 00:00, Close all production sleeves to test lower I sand interval. 11:30, lower I producing-33 mscfd net, 254 BWPD with 400 scfm lift rate. 15:00, Open lower H production sleeve. 9/3/12 06:00 lower H producing -95.1 mscfd net, 624 BWPD with 576 scfm lift rate. 10:00, Close lower H production sleeve and open upper H production sleeve. 9/4/12 08:30, upper H producing 36.5 mscfd net, 254 BWPD with 500 scfm lift rate. 10:00 close upper H production sleeve and open lower G production sleeve. 18:00 lower G producing 134 mscfd net, 302 BWPD with 700 scfm lift rate. 21:30, Open lower G frac sleeve. 9/5/12 14:00, lower G producing 26.7 mscfd net, 249 BWPD with 300 scfm lift rate. 16:30 Close lower G production sleeve and frac sleeve and open upper G production sleeve and frac sleeve. 9/6/12 06:00 upper G producing -147 mscfd net, 672 BWPD with 300 scfm lift rate. Shut in well at 10:00. Open all frac sleeves and production sleeves at 18:00 and return well to N2 lift. At 00:00 well producing 680 mscfd net, 1,310 BWPD with 300 scfm lift rate. 9/7/12 06:00 well producing 365 mscfd, 1,310 BWPD with 300 scfm. 18:00 well producing 323 mscfd, 1,171 BWPD with 300 scfm lift rate. 00:00 well producing 254 mscfd, 720 BWPD with 300 scfm lift rate. 9/8/12 06:00 well producing 246 mscfd, 1,373 BWPD with 300 scfm. 15:00 well producing 590 mscfd net, 1,373 BWPD with 250 scfm lift rate. 00:00 well producing 193 mscfd net, 1008 BWPD with 250 scfm lift rate. 9/9/12 06:00 well producing 205 mscfd net, 922 BWPD with 250 scfm lift rate, 15:00 well producing 182 mscfd net, 840 BWPD with 250 scfm lift rate. 00:00 well producing 183 mscfd, 1008 bwpd with 250 scfm lift rate. 9/10/12 06:00 well producing 205 mscfd net, 1080 bwpd with 250 scfm lift rate, 15:00 well shut-in at choke, 18:30 shift all production and frac sleeves closed, 00:00 well producing 175 mscfd, 0 BWPD with 250 scfm lift rate with choke full open. 9/11/12 06:00 well producing only N2 , -57 mscfd with 250 scfm lift rate. 11:00 shut down N2 lift to equalize tubing and IA. 23:00 open well to 30/64 choke. 00:00 well open on bypass. 9/12/12 06:00 Well producing 271 mscfd net, 0 bwpd with 150 scfm lift rate. 15:00 well producing 281 mscfd , 0 bwpd with 150 scfm lift rate. 9/13/12 09:00 Start injecting N2 via Tubing injecting wellbore fluids to I sands. Total N2 Pumped = 89,500 SCF @ 3246 psi Final WHP. 11:30 SLU pull SSSV frac sleev T=2700 psi 13:00 SLU RIH with PX plug. Set down @ 5775'. Work tool. POOH inspect plug. 15:00 Redress PX plug. SLU RIH with PX plug to 6219'. Work Tools. No positive sign of plug set& latch. POOH 17:00 SLU at surface. PX plug sheared in hole. Call for plug set-check tool. 21:00 RIH w/Check-Set tool. Back @ surface w/o pin shear. PX plug not set 22: 45 RIH retrieve PX plug. Shut DOwn In Progress 9/14/12 11:00 RU SLU. RIH with PX plug to set in 2.75" profile at 6219'. No positive sign of plug latch and set. POH to surface. Plug left in hole 19:00 RIH with GS and retrieve PX plug 19:30 RIH with BO selective tool and work tool through 2.75" profile at 6219' until tool passes easily up and down through profile 20:30 RIH and latch PX plug in 2.75" profile at 6327'. Tubing =2150 psi 23.26 23:26 Set 5' Equalizing Prong in PX Plug 23:26 Run J selective tool to open Lower G Sand production sleeve at 5815' POOH 23:59 Tubing = 1840 psi RIH with BO selective tool and verify 5815" production sleeve is open. Sleeve open confirmed. POOH. Shut Down SLU. In Progress. 9/15/12 Pumped atomized methanol/N treatment in the lower G interval with 15 bb f methanol and 500 scfm N2. RIH and close t wer G production sleeve, POOH. RIH a en the upper G production sleeve and perfo an atomized methanol/N2 treatment into th upper G interval with 11 bbls of methanol and 500 scfm N2. 9/16/12 N2 and methanol injection treatment completed on the upper G sand w/ 11 Bbls of methanol and 500 scfm N2. .Well soaked 8 hours with the G frac doors and selecta sleeves open brought on line at 0430. Lifting well w/700scfm , WHP 140 psi , IA 725 psi, H2O 600 bbl/day, gas gravity .938(N2) Plan is to continue flow back 24-48 hours until J-pad ready for Expro. 9/17/12 Continue to N2 lift, well kicked and water rate increased to 850 day, chlorides up to 10,000 ppm from 8000 ppm, 150 mscfd gas 1 mmscfd nitrogen SG .903 (previous .940). N2 membrane unit shut down due to a mechanical problem. Shut well in to perform build up. IA pressure holding/WHP rising. 9/18/12 Separator bypassed to tank WHP Avg. 88 psi, IA 725 psi, 350 bbl/day H20. Well is free flowing with gas break out. Atmospheric tests of vapor indicate methane. 9/19/12 Stood down part of the day for high winds and equipment needs. Slick line shifted G-zone upper sleeves closed to gather data on the lower G. [RIH Slickline 3.5"42B0 shifting tool in up position (up to close). Shifted closed upper G- sand production sleeve at 5654' and frac port at 5577'.] 9/20/12 Lower G sand only open to tank, bypassing the seperator. Very slight blow of gas. • 01-1 WELL LOG TRANSMITTAL To: State of Alaska July 19, 2012 Alaska Oil and Gas Conservation Commission Attn: Howard Okland 333 W. 7th Ave., #100 Anchorage, AK 99501-3539 RE: MWD Formation Evaluation Logs: BRU 242-04 AK-MW-0009498073 API #: 50-283-20164-00 BRU 242-04 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVDss TRIPLE COMBO Logs: 1 Color Log 2" x 5" MD TRIPLE COMBO+BAT Sonic Logs: 1 Color Log 2" x 5" TVDss TRIPLE COMBO+BAT Sonic Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3539 Fax: 907-273-3535 Buster.Bryant @halliburton.com Date: 9 C‘ =f o- Signed: NAL"— ./'!/) Alaska DNR,Division of Oil&Gas zvz-mil • S X47 C) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Reservoir Description Tool - RDT: BRU-242-04 Run Date: 6/18/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU-242-04 Digital Log Image file, RDT Report 1 CD Rom 50-283-20164-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 9 W11- Signed: PAC Z4z-cg • Z Z-04(0 Regg, James B (DOA) From: Beluga River Company Man [n129cm @conocophillips.com] Sent: Wednesday, July 11, 2012 12:25 PM c'y 7b 1'i To: Regg, James B (DOA) �7 Subject: RE: BRU 244-23 Diverter Test Mr.. Regg Charlie Hunington, the tool pusher that witnessed the test, arrived today. I questioned him on the test. He stated that the initial test on the check valve leaked. There was no external leaks visible. It was re-pressured but continued to leak. The toolpusher found the bleeder valve on the test manifold had not been sufficiently close. There was fluid leaking out the bleeder. The same scenario happened on the annular test. When the tool pusher found the bleeder leaking again the driller was reprimanded. When the inspector comes out on the next test we should be able to recreate it for him. We are now estimating being able to test the diverter on Saturday. I will give you and update Friday morning on the timing. CG Donnie � LA Thanks Donnie Lutrick ettft 263-3010 PS: The office phone will be down most of the day. We are moving the office from C pad to J pad. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, July 09, 2012 11:41 AM To: Beluga River Company Man Cc: Baca, Hank Subject: [EXTERNAL]RE: BRU 244-23 Diverter Test See attached; I would appreciate your attention to this request(referring to test charts for 6-24-12 BOPE test). Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Beluga River Company Man [mailto:n129cm@conocophillips.com] Sent: Monday, July 09, 2012 7:31 AM To: Regg, James B (DOA) Cc: Baca, Hank Subject: BRU 244-23 Diverter Test Jim, This is a heads up for the upcoming diverter test here in Beluga. We are in the process of moving the rig from 243-04 to 244-23. Best guess at this time is we will be ready to test our diverter on Thursday. I will send you an update when the timing becomes more definite. Thanks Donnie Lutrick/ Robert Wall Rig Supervisors Doyon Rig #1 Arctic Fox Beluga 263-3010 1 amt 2-92'-04- • • f • Z1 z a41 o Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, July 09, 2012 11:41 AM To: 'Beluga River Company Man' Cc: Baca, Hank Subject: RE: BRU 244-23 Diverter Test Attachments: RE: FW: See attached; I would appreciate your attention to this request(referring to test charts for 6-24-12 BOPE test). Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Beluga River Company Man [mailto:n129cm@conocophillips.com] Sent: Monday, July 09, 2012 7:31 AM To: Regg, James B (DOA) Cc: Baca, Hank Subject: BRU 244-23 Diverter Test Jim, This is a heads up for the upcoming diverter test here in Beluga. We are in the process of moving the rig from 243-04 to 244-23. Best guess at this time is we will be ready to test our diverter on Thursday. I will send you an update when the timing becomes more definite. Thanks Donnie Lutrick/ Robert Wall Rig Supervisors Doyon Rig#1 Arctic Fox Beluga 263-3010 1 • . 13Pck 29z- °A, Zizo4tO Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, June 27, 2012 8:57 AM To: 'Beluga River Tool Pusher' Subject: RE: FW: Appears to me the annular took 3 attempts to get 3500psi test; and 2 attempts to get 5000psi test on check valve. Please clarify. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Original Message From: Beluga River Tool Pusher [mailto:Nabors129ToolpusherOconocophillips.com] Sent: Tuesday, June 26, 2012 2:48 PM To: Regg, James B (DOA) Subject: FW: Original Message From: Beluga River Company Man Sent: Tuesday, June 26, 2012 2:40 PM To: Beluga River Tool Pusher Subject: FW: Scott Heim - Jimmy Greco BRU Rig Supervisors Doyon Rig #1 Arctic Fox 263-3010 Office 263-3024 Rig Floor Original Message From: Beluga River Company Man Sent: Tuesday, June 26, 2012 2:37 PM To: N129tp0conocophillips.com Cc: Beluga River Company Man Subject: 1 . • . • 0 r2.. 4' A..., i y ir,•-• '0' 7,-.Z i/ .j / r , ,..f-,L,/ '?„-,-1,, '' , « , ■.„, 4- -1". .,' i, " ',"' )>'■ ,.))11 14 'CP') . -... ,,,... ... ...) 4 :/.. .. !' :;"ie •C'' . - )1 . ,4 . ■ v - , ,.\ A ? F' Or ."...., . . I., . ..,..s. At ... ..■ ir , -_-_•;: 1 ,..., • 0 . , , . . .,, 'I ,■ ,' - 1 ' / . .)... c / . , 71 -4 • „.. . . „, ' r 4',.:4•'• s '7 ' ' 4.4e,:t(\t' .1,,-,' , % ,: .', „..,- 0 . . , ,'‘... ..' ' `,;.t c.* -; N, 0 ', /SN 0 .,..,, 1-) '-'6- I 7r. • SUITE OF ALASKA 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 David Ross 4 t Completion Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Unit, Undefined Gas Pool (G, H 8v I Benches), BRU 242-04 Sundry Number: 312-238 Dear Mr. Ross: 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, Cathy . Foerster Chair, Commissioner DATED this 3 day of July, 2012. Encl. • • STATE OF ALASKA Mt(ALASKA OIL AND GAS CONSERVATION COMMISSION 44 / 2—'APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate E Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate 0 , Alter Casing❑ Other: FLew 'GSt- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc Development 0 Exploratory ❑ 212-041 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 50-283-20164- -00 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: !j E c' property line where ownership or landownership changes: v Spacing Exception Required? Yes ❑ No IS BRU 242-04 . JUN 2 Pool(G,H I Benches E 0; 10.Field/Pool(s): Belu a River Undefined Gas o0 9.Property Designation(Lease Number): g ( ) �.. A-029656 ' A 0GCr, 11. PRESENT WELL CONDITION SUMMARY `�L� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7,221' 6,650 7,126 6,556 Casing Length Size MD TVD Burst Collapse Structural Conductor 110.5' 20" 110.5' 110.5' Surface 3,316.5' 9.625" 3,335' 2,831' 8,920 7,110 Intermediate Production 7191.5' 7" 7,210' 6,640' 11,830 11,650 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5,620'-5,634',5,750'-5,766', 5,072'-5,086,5,200'-5,216', 4-1/2",12.6 lb/ft x L-80 4-1/2" 5,459' 6,190'-6,206',6,260'-6,280', 5,634'-5,650',5,703'-5,723', 3-1/2",9.3 lb/ft 3-1/2"- 6,447' 6,300'-6,305',7,100'-7,111' 5,742'-5,747',6,531'-6,542' Packers and SSSV Type: 1 Premier Production Packer&4 Premier Packers and SSSV MD(ft)and TVD(ft): Isolation Packers,WRSSSV 5,514,5,682,5,862,6,233,6,381,534'MD 4,968',5,133',5,310',5,676',5,822,534'TVD 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/6/2012 Commencing Operations: Oil ❑ Gas El • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name David A.Ross Title Completion Engineer Signature � _ Phone 907-263-4191 Date •=0)-‹ _ 6/25/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '3/7$ ?q,,. 7 Plug Integrity 111 BOPITest i( Mechanical al I ty Test ❑ Location Clearance ❑ Other: St_b ri C 13 L- F, C.-ii/t- > ''1L .- 45 Co Pkix 01,....{S.S rU-1_,„ b i"/v___ 60—1 z Z � f/ c , r X" Sec.b,.... eLs d isp,t,s e f( 0-- Subsequent Form Required: /0— Li O 7 /�-7 '. , APPROVED BY' /--.2 Approved by lam . ' 6. p ,,..___.r- COMMISSIONER THE COMMISSION Date: 7- 3 -/a- . ROM% JUL 03 201/ jrnea•Dyplicate Form 10 403 vised 1 2010 Y / • 1110 z"Ci:- 4 irAss '- ConocoPhillips conooliaps BRU 242-04 Completion Overview The BRU 242-04 completion covered under PTD# 212-041 is anticipated to start on 6-26-12 following the cementing of the 7" production casing and finish around 7-31-12 following the post fracturing flow • testing. 11' of Beluga I sand pay, 60' of Beluga H sand pay and 30' of Beluga G sand pay were selected for completion after the LWD log and RDT analysis. After cementing the 7" production casing the wellbore will be cleaned and displaced to filtered kill weight KCI/NaCL completion brine followed by running a cement bond evaluation log. 6 target intervals will then be tubingrnveyed perforated • simultaneously prior to running the lower 3 1/2' completion consisting of production packer and four era,ions between the isolation rings be s aced out across the erft�r�t isolation packers. Carbide blast g p � �� packers. Ball drop frac sleeves will be positioned above the blast rigs in each interval and screen wrapped production sleeves will be placed below the blast rings After spacing out the lower completion all five packers will be simultaneously hydraulically set . The upper'completion will then be run consisting of 4 %" tubing with a chemical injection sub (CIS), a gas lift andrel (GLM) and a w ireline retrievable sub surface safety valve (WRSV). After landing the completion al0 K frac tree will be installed to facilitate the • post rig fracturing operations. a Fracturing and support equipment will then be mobilized torC pad and five independent frac jobs will be performed with an estimated 100K lbs of curable resin coated mic proppant and 30K gallons of guar- borate water based frac fluid. A final cleanout and potential N2 liffwill be performed after the fifth frac job at which time the frac tree will be replacedi'witt e production tree the well will be flowed back for a maximum of seven days through well test equipment' efore putting the well on production. All gas and fluid returning during the flowback period will be metered and vented according to the new EPA NSPS ce 0000 regulation pertaining to the flowback of fractured gasx lls ac€P BRU 242-04 Completion ratio =Opens Summar x y£, ~ F s°q*v"` 1. P/U and run a WB assembly and displace the well to filtered kill weight i e. u« 2. R/U E-line and run a cement bond`fog = s�� -'� ✓ 5 �° �°"""�`s• � , 3. Overbalance TCP five target sands simultaneously and pump a FLC pill if required. 6'`i 4. P/U and run a perforation debarring assembly , 5. P/U and run a *lower 3 completion with one production packer and four isolation packers. 6. Space*out"and hydraulically�set all five packers simultaneously. 000 7. P,/U grid run the upper r J2' completion with CIS, GLM and WRSV. .° o'u 8. Space�out and land the`tubing hanger Run in lock down screws. Zlv_ 9. Pressure test the tubing and annulus't 5,000 psi and shear the ball seat. /.. and 10. Install test a 2-way checkt�valve in the direction of flow. 11. Nipple down the BOP stack and install a 10K frac tree. 12. Pressure tes he bonnet anal tree seals to 7,500 psi 13. Release rig, R1O * 14. Move in and rig up., acoled tubing , slick-line and support equipment. 15. Frac zones 1-5 with-*NOOK lbs of 20-40 RC ceramic proppant and - 30K gallons of gaur/borate fluid. 16. Perform CT cleanouts following each frac!required. <'r"'''- 17. Following the 5th frac perform a fin. cleanout and replace the frac tree with the production tree. r. .."7 18. Demobilize the frac and sup.po• -quipment and move in and rig up well testing equipment. I 19. Flow test the well for a ma ' urn of 7 days as per the EPA NSPS 0000 regulation. iii- -231 20. Rig down the well testing -quipment and put the well on production. tS -r'+- BRU 242-04 Page 1 of 1 Completion Summary 6/26/2012 BRU 242-04 IP" Grassroots Well ConocoPhillips Proposed Completion Schematic Coucor(Driven):20',.75',API 5L GRB, Full % % ', , 1 Upper Completion MD TVD Grvd, R3 Below Pad Driven Grade o 1-1u8- 018110' r ( 1) BP6i SCSSSV w/1/4"SS control line 534 534 SSSV 1 r 2) Chemical Inj.Sub w/DCV&3/8"SS control line 5,356 4,812 Coupling Protectors i % II t 3) 4'/z"Camco KBG-2 GLM w/DCK-2(2,500 psi) 5,413 4,869 Cannon oup g ! II ! Tubing clamp protector,over ( cup ilng e,bare line, 2o0 annel (left to I�` 4)XN Profile, 3.725"ID 5,433 4,889 right) 0 3yp line. Low carbon steel.25.25"long. 80-40 GBH-22 Seal Assembly 5,474 4,929' ! ! 5) C I)C Lower Completion TOC+/-3147'MD/2876'TVD ; i I 500'above the top Sterling ; 1 t 6) Liner Setting Sleeve , RS Nipple,4"Seal Bore 5,467 4,922 j Surface Casinq: I 7) 3 1/2"x 7"Premier Production Packer 5,514 4,968 9-5/8",40#, L-80, BTC i Set @ 3335'MD/2831'TVD 8) X Profile,2.813 ID 5,533 4,987 Ii I 9) 3 1/2"Halliburton Frac Door w/2.05"Ball Seat 5,574 5,027 ( 10) 3 1/2"Carbide Blast Rings 5,615 5,067 11) 3 1/2"Selecta Flow Screen w/2.75"X profile 5,651 5,103 t 12) 3 1/2"x 7"Premier Isolation Packer 5,682 5,133 Production Tubing: 2 4 1/",12.6#, L-80, IBT-M to 13) 3 1/2"Halliburton Frac Door w/1.80"Ball Seat 5,734 5,184 5,459'MD/4,914'TVD GL 3 3%",9.3#L-80, IBT-M to . 14) 3 1/2"Carbide Blast Rings 5,745 5,195 5,509"MD,4,963'TVD 4 6 . 5 7 15) 3 1/2"Selecta Flow Screen w/2.75"X profile 5,812 5,261 _ 8 9 - _ 16) 3 1/2"x 7"Premier Isolation Packer 5,862 5,310 G Sand Peforations(5 spf) r - 10 IIIIIVU @ 5,620'-5,634'(14') = 11 . ----- - 17) 3 1/2"Halliburton Frac Door w/1.55"Ball Seat 6,140 5,585 12 • t 13 - 18) 3 1/2"Carbide Blast Rings 6,185 5,629 G Sand Peforations(5 spf) , - = 14 - �\_ �. @ 5,750'- 5,766'(16') _ 15 _ -_ - 19) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,217 5,661 - 16 la a ' 20) 3 1/2"x 7"Premier Isolation Packer 6,233 5,676 17 = H Sand Peforations(5 spf) r - -_ 18 @ 6,190'-6,206'(16') _ 19 -- - 21) 3 1/2"Halliburton Frac Door w/1.3"Ball Seat 6,249 5,692 H 20 • 22) 3 1/2"Carbide Blast Rings 6,257 5,700 H Sand Peforations(5 spf) - - 21 - _ r �' 22 �� 23) 3 1/2"Selecta Flow Screen w/2.75"X profile 6,325 5,767 @ 6,260'-6,280'(20') _ _ _ ) 6,300'-6,305'(5') 23 24 - - 115 a 24) 3 1/2"x 7"Premier Isolation Packer 6,381 5,822 1 Sand Peforations(5 spf) p e ;_ AA 25 �\_.-.l 25) 1"SO Ball Seat w/Wireline Entry Guide 6,442 5,882 @ 7,100'-7,111'(11') __- Production Casing; • '7",26.00#,L-80, BTC-Mod Set @ 7200' MD/6685'TVD • • Schwartz, Guy L (DOA) From: Todd Driskill [tdriskill @doyondrilling.com] Sent: Wednesday, May 02, 2012 4:49 PM To: Schwartz, Guy L (DOA); Shultz, Steve(Orbis Engineering, Inc.) Cc: Ron White Subject: RE: Emailing: AF 21 2M Diverter.pdf, Arctic Fox Rig 1 3d choke manifold.pdf, ARCTICFOXBOPSYSTEMANDCONTROL.pdf, 11.5 Hydril Stack.pdf, Vetcogray Cellar Detail SP-5861-7 (1).pdf neut �4 " Guy, PTO O -24 2 - oct Yes, this is the same stack used on the Q-4 Well. We sent the Shaffer Stack used last year at Beluga, out for Rebuild, and it doesn't look like we will get it back in time for the Beluga work. Our original plan was to use the Shaffer Stack at Beluga, and had originally sent that information to Conoco. Sorry for the Confusion. Thanks, Todd Driskill Drilling Operations Manager Doyon Drilling, Inc Main 907-563-5530 Direct 907-565-4249 Cell 907-223-0537 Original Message From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, May 02, 2012 4:39 PM To: Todd Driskill; Shultz, Steve (Orbis Engineering, Inc. ) Cc: Ron White Subject: RE: Emailing: AF 21 2M Diverter.pdf, Arctic Fox Rig 1 3d choke manifold.pdf, ARCTICFOXBOPSYSTEMANDCONTROL.pdf, 11.5 Hydril Stack.pdf, Vetcogray Cellar Detail SP-5861-7 (1) .pdf Todd, If this is the repsol Q4 stack then we have it on file already. I thought maybe you were bringing this BOP from out of state or in from a recent rebuild. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) Original Message From: Todd Driskill [mailto:tdriskill @doyondrilling.com] Sent: Wednesday, May 02, 2012 4:36 PM To: Shultz, Steve (Orbis Engineering, Inc. ) Cc: Schwartz, Guy L (DOA) ; rwhite @doyondrilling.com Subject: RE: Emailing: AF 21 2M Diverter.pdf, Arctic Fox Rig 1 3d choke manifold.pdf, ARCTICFOXBOPSYSTEMANDCONTROL.pdf, 11.5 Hydril Stack.pdf, Vetcogray Cellar Detail SP-5861-7 (1) .pdf Steve, This is the same BOP Stack used on the Repsol Q-4 Well this season. This is the BOP stack that has been in use with the Arctic Fox other than your wells in Beluga. 1 It 410 • I am not certain what "certifications" the State is needing? Are they wanting the original certification of the BOP, the latest inspections reports, or the latest State BOP test reports. The BOP Test reports should be on record with the State. This is something new and I'm not sure exactly what Guy is looking for. Thanks, Todd Original Message From: Shultz, Steve (Orbis Engineering, Inc. ) [mailto:Steve.Shultz @contractor.conocophillips.com] Sent: Wednesday, May 02, 2012 3:47 PM To: Todd Driskill Cc: guy.schwartz @alaska.gov Subject: FW: Emailing: AF 21 2M Diverter.pdf, Arctic Fox Rig 1 3d choke manifold.pdf, ARCTICFOXBOPSYSTEMANDCONTROL.pdf, 11.5 Hydril Stack.pdf, Vetcogray Cellar Detail SP-5861-7 (1) .pdf Todd, I contacted AOGCC to let them know that we planned on using another BOPE system for the Beluga wells this summer since the Shaffer system needed some work. Guy Schwartz had some questions on the certification of the equipment. Can you e-mail that information to him and myself. Thanks Steve Guy, I think I told you Cameron on the phone but this stack is really a Hydril. Steve Original Message From: Driskill, Todd (Doyon Drilling) Sent: Friday, April 27, 2012 6:08 PM To: Shultz, Steve (Orbis Engineering, Inc. ) Cc: arcticfox @doyondrilling.com; rwhite @doyondrilling.com Subject: [EXTERNAL] FW: Emailing: AF 21 2M Diverter.pdf, Arctic Fox Rig 1 3d choke manifold.pdf, ARCTICFOXBOPSYSTEMANDCONTROL.pdf, 11.5 Hydril Stack.pdf, Vetcogray Cellar Detail SP-5861-7 (1) .pdf <<AF 21 2M Diverter.pdf>> St <<Arctic Fox Rig 1 3d choke manifold.pdf>> ev <<ARCTICFOXBOPSYSTEMANDCONTROL.pdf>> e, <<11.5 Hydril Stack.pdf>> <<Vetcogray Cellar Detail SP-5861-7 (1) .pdf>> Attached are the drawings and information of the BOP equipment. As per our Phone conversation, we need to switch the Shaffer BOPE to the Hydrill. The Shaffer was found to have some needed repair in the seal area and there is a chance we will not get it back in time. Also the Accumulator was sent out after the last well for service and there is a possibility it will not make it back. We have committed to the Hydril stack and a rental Accumulator unit. The accumulator is a plug and play system, self contained needing only Power and Air. Will not be a problem to rig up. The Hydril BOP equipment was used last well. It has only one well on it since Third party inspection. The crews are familiar with it. BOP complete with 2 sets of 4" Rams, 7" rams. One set of 2 7/8 x5" variable rams available for rental. We will not have a problem covering all the pipe sizes. Thanks, Todd 2 • Original Message From: Ron White Sent: Friday, April 27, 2012 1:38 PM To: Todd Driskill Subject: Emailing: AF 21 2M Diverter.pdf, Arctic Fox Rig 1 3d choke manifold.pdf, ARCTICFOXBOPSYSTEMANDCONTROL.pdf, 11.5 Hydril Stack.pdf, Vetcogray Cellar Detail SP-5861-7 (1) .pdf This will be the new drawings once the accumulator rental is approved. 3 • • , , 1 ...... „. ,.. ? ,1-i-'-' 1 ; '. ... I''' ' pi ?.,.. a- y e t \ 0 g E 3-r 1 1 / lw a (1 e E --7 = I L" I IN \ ( 5 i I , IV I i � u2 R I � �= i i ?.I I 1 — — N!H - r 1 Si f , ° !- I 4 0 1 -- 9 I i , I I i I _. i IT, i.____MAad; J„ d _ ' / If Z Iii 2 j I J1 k N N' gi aJj avd W I Iv � I I\ I I ;�\ N,\ i 'o I I c i 1° I ei I i Ip I � • • ITEM DESCRIPTION 1 11" 5K HYDRIL GK ANNULAR RECEIVED 3 2 11" 5K 11" 5K DRDRIING DOUBLE SPOOL w/ 3-1/8" 5K OUTLET::_. MAY 2 2��2 t 4 2EA. 3-1/8" 5K HYDRAULIC VALVES 5 2EA. 3-1/8" 5K MANUAL VALVES 1 ATCC 4 11" 5K HYDRIL SIB! CATS 41 3'-7" 1 2'-10" 18'-6" \ u „., . - J r. � c . Cr• 14'1 mile , t F I r °Q° riiik■ ' -.'• - ;1. .:r. lin 116"" '''.'.''.''''''.11.""11 i IrokilitpAgy, - , . 1..,,,, 11 a01101M ..J / I A i!WIZ I7I! .1 4'-6n 1 d U - -4 N II 1 i .4. 12/5/05 Beluga Project The information contained in this drawing is 1DOYON the sole property of Doyon Drilling Inc.Any ins reproduction in whole or part without the `• ouN Arctic Fox s. express written consent of Doyon Drilling DRILLING ,„,r Sub Section } Inc.is prohibited. Hydril 11"5M Stack `N. wwwn trot.j \""snydnisiack j w • 1 1/ NI 11"5.000 psi HVDRIL GK I 5 000 psi -,"--Ir ora 'I•i' � .7IY mililMeom •I•"....�'t.r �.. !>I• liwii-c, 11'5.000 psi II C=.M:IQ- •3,,I:�l!'� Drilling SpoOI . M O "1 34"Outlets IL•.....All�a�..\!, SI.�JJ..`�,I " '% 10,1"'MEM • s . Imo• = LION" e a c111Q =fin+M' ® - H r i-a i11»=r.fir. lWA=INIM. r 4.. J Y }•,p. .r' r ;:.. O .0 s •! { C, 1 1 1 I Oct 20,2005 Arctic Fox-Rig 1 The Information contained In this drawing Is the sole property of Doyon Drilling Inc.Any VOYON .. NTs reproduction In whole or part without the `\ RTr 1 express written consent of Doyon Drilling DRILLING ...\ Sub Cross Section I Inc.Is prohibited. �, 5.w. tt..wm o.t., ‘�: a Y iw it W 0301 I VALVE LEGEND PT.isP�0T©T0T1I• 1 BYPASS 2 KILL U II 3 CHOKE . I 4 BOTTOM RAMS r 5 BLIND RAMS I UM 7T 6 TOP PIPE RAMS Hydril 11",5M,Annular BOP 6 ACCUMULATOR: CONTROL TECHNOLOGY INC 7 ANNULAR 67 8" 6 STATION 3.125",5M,Side Outlet Typ. TRIPLEX PUMP: 1/208 VAC, 20 HP • AIR PUMP: 2/40:1, 8GPM, 3,000 PSI I I FLUID RESERVOIR: 165 GALLON 0 (VIII,--=.�_.17JII4 I. .I� :��.V: � .'_— 132.3" Hydril 11",5M,Double Ram 41 0" BOP ::110101 A CCIIII❑1 ❑II'� 3"ID Kill Hose :, r, OPEN CLOSE 3"ID Choke Hose _ _ _ — O O O O 'O O , [01 ' b _ _ CHOKE ..U_.II -mtillik OPEN CLOSE � O 3.125",SM,HCR Valve W— O O ,.E / �-. i'��L KILL .,. 3.125",5M,Gate Valve / • I 41k• •____ 1 -Iv 03-< -- • .1. -- 0 R-. .._ , m O m ,. x„. x Z II v imp' -�1II®III I vm rn mr CO Z y Z H �� m � m ' :IP. ■n _ix x . C c 7J z C Z w m G o r— _L . m o °?. m • + D 0 r II 111 411 t { �I ( iI?rTii I 1 . ,,, , .1,4,, , —'C: j ,1 l ij I ;I {, ' 1„ „ c,/ 1 i b , I .. 1 1�. + i,, ,„ t , imml, 1 — i li \' I I„,s 0. 11 �II\ I -- I r ,,” . j I'� '� , Ali I Al II I; I IH � � oS N g: F°E — 3tl DL3 N,°-pnaa- o - n '9 - o2'0 iI ti �1 _ .J . f Page 1 of 1 Schwartz, Guy L (DOA) From: Shultz, Steve(Orbis Engineering, Inc.) [Steve.Shultz @contractor.conocophillips.com] Sent: Thursday, April 26, 2012 9:43 AM To: Schwartz, Guy L (DOA) Subject: FW: ignition source Guy, I spoke to soon, I was under the impression that the well houses were class 1 div 1 but they aren't, but with that said there are no open flames around those well houses for obvious reasons. So the question still is do I need to be 75 feet away from the house. Steve From: Shultz, Steve (Orbis Engineering, Inc.) Sent: Thursday, April 26, 2012 9:14 AM To: quy.schwartz©alaska.gov Subject: ignition source Guy, What is the AOGCC's definition of an ignition source? We have well houses out at Beluga that are all Class I Div I with no open flames. Would that suffice as a non-ignition source? The reason I'm asking concerns the diverter on BRU 242-04. We will be having it go past one of the well houses and I'm not sure if the end of it will be 75 feet away from the well house. Thanks, Steve 5/2/2012 • �\ 4 ITS 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 C. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Beluga River Field, Beluga River Undefined Gas Pool, BRU 242-04 ConocoPhillips Alaska, Inc. Permit No: 212-041 Surface Location: 201' FNL, 368' FEL, SEC. 4, T12N, R1OW, SM Bottomhole Location: 2340' FNL, 792' FEL, SEC. 4, T12N, R 1 OW, SM Dear Mr. Alvord: 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, Cath P. Foerster Chair DATED this �2 day of April, 2012. cc: Department of Fish 8s Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) r • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL FEB 1 2012 20 MC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zonf 1 II' o f r:. k�a�� m°missil� Drill Q ` Re-drill❑ Stratigraphic Test ❑ Development-Gas 0 Service-Supply ❑ Multiple Zohe ✓ Coalbed Gas BC ragGas Hydrates Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ _�_ F1 Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ^ BRU 242-04 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:7248' TVDSS: 6685' ' Beluga River Field / 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): �c'6tt,,,c1� i iz4l rt d F4z'l Surface:201'FNL,368'FEL,Sec.4,T12N,R1OW,SM - �`�3•~'-',ø1 -029656 k' rlin yg,22,4Z. Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1723'FNL,677'FEL,Sec.4,T12N,R10W,SM n/a 6/11/2012 Total Depth: 9.Acres in Property: 14.Distance to 2340'FNL,792'FEL,Sec.4,T12N,R10W,SM 1394 7 ..i Nearest Property: 8613'from MHT lease 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:/J(„03eet 15.Distance to Nearest Well Open Surface:x- 315291 y- 2619715 . Zone- 4 GL Elevation above MSL: 92 feet to Same Pool: BRU 211-03,110' 16.Deviated wells: Kickoff depth: 400 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) :25171 p yc, y'f-f Maximum Hole Angle: 42.9° deg Downhole p ig3` p�V Surface jgepsig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) n/a 20" 154.19# X-65 Welded 92' 18.5 18.5 110.5 110.5 Driven to Refusal 12.25" 9.625" 40# L-80 BTC 3356' 17.5 17.5 3374 • 2876. 733 sx, 12ppg Lite 8.75" 7" 26# L-80 BTC 7232' 16.5 16.5 7248 6685 294 sx, 10.5 ppg Class G 4.5" 12.6# L-80 IBTM 7100' 15.5 15.5 7085 6570 Production Tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD ND Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Ell Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements Q 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Printed Name C. Alvord Title Drilling Manager Signature ',J _ n _, Phon 265-6120 Date 2./14 (2o(Z A (� 1%l,� Commission Use Only Permit to Drill API Number: /`y'� j Permit Approval See cover letter Number: 2l 7 L// 50- x' 16 4-1"''�� "L°I Date: \t\(L. for other requirements (: If box is ch cked well ma not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: v❑7 Conditions of-approva ,Y p P LA,1 t' 1 2 ( ❑ No [ Mud log req'd: Yes ❑ No [,]� � �os� Samples req'd: Yes Other: / J /, t H2S measures: Yes ❑ No ❑✓' Directional svy req'd: Yes Q� No ❑ G-Ec /J_ I �-� .- r� .. `z r r (A (.c�r..r. c 1 � �. 2 07 CC�`,� '� 4� APPR VED BY THE COMMISSION DATE: 4- /4t j r ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid for 4 n�. lt4 f 010 eidl�te:oofrp iroval(20 AC 25.005(g)) Submit in Duplicate �^ ConocoPhillips Alaska, Inc. • • Post Office Box 100360 ✓ .f . Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 February 7,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill BRU 242-04 Gas Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore gas producer well in the Beluga River Unit. The surface location will be on the pre-existing pad containing wells 211-03,and 224-34. The expected spud date is June 1st,2012 conducting operations with Doyon Arctic Fox. BRU 242-04 proposed well design is to drill a 12-1/4"surface hole to approximately 3,374' MD/2,876' TVD on diverter vent system. Then 9-5/8"surface casing will be run and cemented to surface.Next,the 8-3/4"production hole will be drilled to 7,248' MD/6,685' TVD on a 5,000 psi BOPE system. Mud logs will be taken from the shoe of the 9 5/8"casing to 7,248' TD. The production hole section will penetrate the Sterling sands through the Beluga I. Then 7" production casing will be ran to total depth and cemented to 3,142' MD, approximately 500' MD above top of Sterling A. Following drilling operations,the 7"casing will be perforated in the zone of interest. To commence the proposed drilling program,CPAI is seeking approval for variance 20 AAC 25.035(h)(2). This variance is to regulation 20 AAC 25.035(c)(1)(A)specifying vent diameter size. The Doyon Arctic Fox is equipped with a 12"vent line compared to the requested 16". Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by / 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. a/ If requiring further information,please contact Steve Shultz at 263-4297 or Chip Alvord at 265-6120. Sincerely, Steve/Shultz Drilling Engineer iLt A; Conoco Phillips Alaska, Inc. BRU 242-04 Grassroots Well ConocoPhillips Compleation o Schematic Conductor(Driven): 20",.75",API 5L GRB,R3 Driven to Refusal 91' Below Pad Grade 11-18-08 f Halliburton H ES HO stage tool( +/-4000'MD —CONTINGENCY IF THERE ARE LOST CIRCULATION I PROBLEMS-- I i i r I TOC 500' BP6i SCSSSV with%"SS control line to surface TOC+/-3147'MD/2876'ND aSterlinop 9 n+1-550'MD r i Surface Casing: j 9-5/8",40#,L-80,BTC Set @ 3374'MD/2876'TVD(-265'TVD abov, i Sterling-A) Chemical injection port with 3/8"SS control line t _- +/-500'MD Beluga H and I will require Fracturing Operations 4-%"Camco KGB-2 GLM w/1"DCK2 shear valve -T -I • RA Tag in 7"casing(on 10'pup joint) i 4%" "X"Nipple w.3.813"ID i Formaton: Estimated Tops: Pore Pressure -=1 i Baker 80-47 Polished Bore Receptacle s on i_ +/-5739'MD/+1-5201' r I Beluga H ND 6 5-9.4 ppg Four Isolation Packers with: _ -Ball Drop Actuated Frac Sleeve +/-6519'M D/+/-5969'Blast Rings � `�y� Beluga I ND 9 h PPg Conventional Sliding Sleeve r� — TNT i� i� ASP i— Beluga I Base 9 6 ppg r■ +/-7044'MD/+/-6486' Fifth Isolation Packer with: _ = �= ND Ball Drop Toe Plug S,1 V;"XN"Nipple V: WLEG Production Casing; 7",26.00#,L-80,BTC-Mod Set @ 7248'MD/6685'TVD BRU 242-04 (+/-204'MD Below Beluga I Base) prepared by Steve Shultz/Dave Ross 01/27/2012 Sperry Drilling Services Directional Plan wp11 ORIGINAL s • Application for Permit to Drill Document Beluga River Unit 242-04 Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 242-04. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat ident'ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 201'FNL, 368'FEL, Sec 4, T12N,R1OW NAD 27 RKB Elevation 110.0'AMSL ' Northings: 2,619,715.42' Eastings: 315,291.27' Pad Elevation 92.0'AMSL Location at Top of Productive Interval 1723'FNL, 677'FEL, Sec 4, T12N,R1OW (Sterling A Sand) NAD 27 Measured Depth, RKB: 3,647' Northings: 2,618,198.16' Eastings: 314,960.23' Total Vertical Depth,RKB: 3,141' Total Vertical Depth, SS: 3,030' Location at Total Depth 2340'FNL, 792'FEL, Sec 4, T12N,R1OW NAD 27 Measured Depth, RKB: 7,247' • Northings: 2,617583.60' Eastings: 314,836.40' Total Vertical Depth, RKB: 6,685' Total Vertical Depth, SS: 6,575' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see attachment: Directional Plan No close approach issues exist. Separation factors are above 10.0 from surface to TD. The'/4mile pool scan of the top of Sterling A sands show the closest in pool to be 211-03 wellbore 110'away at 382' MD. The next closest in pool is 224-34. This producing well is 210' away at 283' MD. And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,as applicable; Please reference BOP schematics on file for Doyon Arctic Fox. rTh. r ' t' I .E , C s • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The production hole is expected to penetrate near virgin reservoir pressures of 3,042 psi in the Beluga I-sands. This maximum down hole pressure was documented during the MDT's taken on the offset well 243-34 in 2008. The maximum potential surface pressure(MPSP)while drilling 242-04 is calculated using above maximum reservoir pressure, a gas gradient of 0.10 psi/ft,and the estimated depth of the Beluga I-sand top at 5,969' TVD(WP13): I-sand reservoir pressure =3,068 psi I-sand estimated top depth(WP13) =5,969' TVD Gas Gradient =0.10 psi/ft as per 20 AAC 25.005(c)(4)(A) Hydrostatic of full gas column =596.9 psi (5,969' TVD*0.10 psi/ft) MPSP=SIBHP—gas column =2,471 psi (3,068 psi—596.9 psi) (B)data on potential gas zones; The well bore will penetrate the Sterling A-C and the Beluga D-I gas zones. And (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached BRU 242-04 Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300); A procedure is on file with the commission for performing formation integrity tests. For BRU 242-04,the FIT will occur after drilling out the 9-5/8"surface shoe track plus 20' of new formation. The formation will then be pressured to 16.0 ppg EMW or until leak off occurs,which ever comes first.A required minimum leak off of 11.0 ppg EMW must be obtained; L ��, N 1(. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed Casing Program Casing Weight Top Bottom OD Hole Size (lb/ft) Grade Connection Length MD/TVD MD/TVD 20" Conductor 154.19 Weld 92' 18.5'/18.5' 92'/92' 9-5/8" 12-1/4" 40 L-80 BTCM 3,356' 17.5'/ 17.5' 3,374'/2,876' 7" 8-3/4" 26 L-80 BTCM 7,232' 16.5'/ 16.5' 7,232'/6,685' 4-1/2" Tubing 12.6 L-80 IBTM 7,100' 15.5'/ 15.5' 7,085'/6,510' RECEIVED MAR 2 8 2012 Alaska Oil& Gas Cons. Commission Anchorage • • Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commis on and identified in the application: fr (4)information on drilling hazards,including (A)the maximum downhole pressure that may,be encountere44•irikriit ufed to determine it and maximum potential surface p "ssure based on a methane gradient; ' �'' y The production hole is expected to penetr‘te. vi riear° rgin reservoir pressures of 3,514 psi in the Bel _a I-sands. This maximum _ down hole pressure was documented difl i the completion 61'232-26 in FebAtary 1985 at a ye • al depth of 6471'. The maximum potential surface pressure(MP€I')while drilling 224-23T is calculated usi.. above maximum reservoir pressure,a gas gradient of 0.10 psi/ft,and"the estimated depth of the Beluga I-sand top .t 5,797' TVD(WP5): I-sand reservoir pressure =3,514 psi 0,0-39 / w- /1. �-y , I-sand estimated top depth(WP05) =5,969' TVD -S ;,U tom. Gas Gradient =0.10 psi/ft as per 20 AAC 25.005(c)(4)(A) /1. Hydrostatic of full gas column =596.9 p • (5,969' TVD*0.10 psi/ft) MPSP=SIBHP—gas column =2,917 e si (3,514 psi—596.9 psi) (B)data on potential gas zones; The well bore will penetrate the Sterling A-C and the Bell ga D- gas zones. " And (C)data concerning potential causes of hole problems 44 as,.nor, ll eo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; 7 See attached BRU 242-04 Drilling Hazards Summ '=j . Requirements of 20 AAC 25.005(c)(5) ,1' U P A An application for a Permit to Drill must be acc one. by h o the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for cone/ J g ation i grity tests,as required under 20 AAC 25. — —""'_" `.,"---," ---:.-.. f7/ A procedure is on file with the commission sr performing formation integrity tests. For BRU 242-04,the FIT will occur after drilling out the 9-5/8"surface shoe track s, s 20' of new formation. The formation will then be pressured to 16.0 ppg EMW or until leak off occurs,which ever comes st.A required minimum leak off of 11.0 ppg EMW must be obtained. Casing and Cementing 'rogram Requirements of 20 AAC 25.00 c)(6) An application for a Permit to Dri must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casin:and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed Casing Program Casing Weight Top Bottom OD Hole ize (1b/ft) Grade Connection Length MD/TVD MD/TVD 20" Co •uctor 154.19 Weld 92' 18.5'/ 18.5' 92'/92' 9-5/8" 2-1/4" 40 L-80 BTCM 3,356' 17.5'/ 17.5' 3,374'/2,876' 7" 8-3/4" 26 L-80 BTCM 7,232' 16.5'/ 16.5' 7,232'/6,685' 4-1/2" Tubing 12.6 L-80 IBTM 7,100' 15.5'/ 15.5' 7,085'/6,510' al ;f'�' a JJJ , yy ., J *_ T t aR 3 1 npir I Pt... I '. ,, E .� i . . a • . 9-5/8" Surface Casing Single Stage Cement Program The 9-5/8"X 12-1/4"annulus will be cemented from TD of 3,374' MD to surface using light weight 12.0 ppg Type I cement. Cement System: Preflush: 40.0 bbls Viscosified Water Nut Plug Sweep Spacer: 24.0 bbls Mud Clean II with red dye Lead Slurry: 733 sacks 12.0 ppg Type I Cement+additives Yield=2.32 ft3/sx Mix Water=9.52 gal/sx Displacement: 255.0 bbls Spud Mud --, Length Capacity Total Total Total Mix Water Slurry Volumes (ft) (ft3) Excess (ft3) (sacks) (bbls) (bbls) Conductor ID x Surface OD 92 51.8 0% 51.8 22.3 9.2 5.0 14.0"x 9.625" Open Hole x Surface OD 3,372 1056.2 70% 1795.5 733 319.5 165 12.25"x 9.625" b Shoe Track ID 85 . 36.2 0% 36.2 15.6 6.5 3.6 8.835" Rat Hole 2 .8 70% 1.4 3.4 .25 1.4 12.25" Total 1884.9 774.3 335 175 Top of Surface casing set at 18.5'MD,surface casing shoe set at 3,374' MD. 7" Production Casing Single Stage Cement Program The 7"X 8-3/4"annulus will be cemented from TD of 7248'MD to 3142'MD(500' above top of Sterling A sand)using light weight 10.5 ppg Class"G"cement. The slurry will consist of gas blocking additives to prevent channeling. If significant lost circulation occurs during drilling,a hydraulic stage cementing tool may be considered for cementing across the Sterling sands. Cement System: I Spacer 40.0 bbls 10 ppg BJ Seal Bond+ 19.8 lbs/bbl Potassium Chloride+67.8 lbs/bbl Barite Lead Slurry 277.9 sacks 10.5 ppg Class G Cement+additives Yield=2.99 ft3/sx Mix Water= 12.32 galls Displacement 241.5 bbls KlaShield Drilling Mud Length Capacity Total Total Total Mix Water Slurry Volumes (ft) (ft3) Excess (ft3) (sacks) (bbls) (bbls) Surface ID x Production OD 235 37.2 0% 37.2 12.5 6.6 3.7 ✓7 8.835"x 7" Open Hole x Production OD 3372 506.9 50% 760.4 254.3 135.3 90.3 8.75"x 7" Shoe Track 85 18.3 0% 18.3 6.1 3.3 1.8 6.276" Rat Hole 10 .84 50% 1.3 .43 .23 0.2 8.75" Total 817.2 273.3 145.4 96 Top of cement at 3,142' MD,surface shoe set at 3,372' MD,production shoe set at 7,246' MD V Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); The 12-1/4"surface hole will be drilled with a diverter system consisting of a remotely operated annular pack-off,full-opening vent line valve,and a 12"diameter vent line. CPAI is seeking approval for regulation 20 AAC 25.035(h)(2). This variance is to regulation 20 AAC 25.035(c)(1)(A)for a 12"diameter. i I r L • Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Mud Program Summary Surface Interval Fluid Properties Mud Funnel API Fluid Drill Depth MD Wt. Viscosity Yield Point Loss pH Solids MBT (ft) (ppg) (cp) (1b/100ft) (cc/30min) (%) 100'-3,374' 8.8-9.6 200-300 40-60 NC—<10 +/-9.0 <7% <35 Surface Interval Summary The 12-1/4"surface hole will be drilled with a fresh water spud mud to an expected total depth of 3,374'MD/2,876' TVD. The spud mud will consist of viscosifiers,pH control,weighting material,and anti accretion/bit balling agents.This fluid will maintain good rheology to remove formation cuttings,prevent loss circulation,promote hole cleaning and ensure good cement to surface. Production Interval Fluid Properties API Fluid / Depth MD Mud Wt. 6 Yield Point Solids Loss ✓ (ft) (ppg) RPM (Ib/100ft2) (cc/30min) pH ("%o) 3,374'-7,248' 9.6-9.8+ 7-9 18-20 <6cc 9.0-9.5 <5 Production Interval Summary The 8-3/4"production interval will be drilled from 3,374'to a planned TD of 7,248'MD/6,685' TVD. The drilling fluid will be a water based shale inhibitive system consisting of 6%KC1 and other proprietary shale inhibitors.Additional well bore strengthening materials designed to prevent lost circulation in the depleted Sterling sands will be included.Also products for stabilization of coal seams and minimizing fluid invasion to prevent reservoir damage will be added. Whole mud dilutions and rheology maintenance will used to prevent differential sticking. Additional focus will be on good hole cleaning practices. These practices include monitoring tripping speeds and PWD data,controlling ROP,pumping regular sweeps,adjusting rheology,and charting drag weights. Fluid weight will have sufficient density to overbalance the pressure of uncased formations penetrated. Sufficient weighting - material stocks will be maintained on site such that the entire mud circulating volume can be raised by a minimum of 1.0 ppg. Diagram of Doyon Arctic Fox Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A-Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A-Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A-Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. ; 1 1I • Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: General Procedure: 1. MIRU Doyon Arctic Fox over pre-installed 20"conductor casing with welded landing ring on conductor. 2. Install diverter&function test same. Notify regulatory agencies 48 hours prior to test. 3. Spud well and drill 12 1/4"hole to the surface casing point at 3374'MD/2876'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing,trip out. 5. Run and cement 9 5/8"40#L80 BTC casing string to surface. • Employ lightweight cement lead slurry to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches th- trface during the cement job. 15o f---�► 5�L� jo 6. Nipple down diverter,nipple up BOP's. Test BOP's. Notify all regulatory agencies 48 hours prior to test. 7. Make up 8 3/4"bit and BHA and RIH to top of float equipment. • Pressure test casing to 3000 psi for 30 minutes • Record results and fax to town 8. Drill float equipment and approximately 20' of new hole i-er • Perform LOT(or FIT if gradient reaches 18 ppg equivalent) — // �p�,� • Record results and fax to town 9. Drill 8-3/4" hole to +/- +/-3,647' MD / +/- 3140' TVD. Run MWD / LWD logging tools in drill string as required for directional measurements and formation data gathering. POOH with drilling assembly. 10. RU Baker core barrel and RIH 11. Core 90 feet through the Sterling"A". 12. POOH and service core barrel,LD same and PU drilling BHA. 13. Continue drilling the 8 3/4"production hole to+/-7248' MD,6685' TVD. 14. RU wire line and RIH with MDT tools for collecting fluid samples and formation pressures. ' 15. PU cleanout assembly and RIH,cleanout to TD,circulate four bottoms up C/o A14 s 1 ? 1'41- 16. Run and cement 7"casing per program to TD(est. @ 7248' MD/6685' TVD). dement casing and bring cement+/-500' above Sterling A sand to 3147'MD. • If there are signs of lost circulation prior to running casing, install a Halliburton HES stage cementing tool at+/- 4000' MD. 17. Run in with a cleanout assembly inside the 7"casing. _ 18. Displace well to clean brine. / T xci)�� W l ,osL re.c r 19. Test casing to 00 nci fur 2n mi„ a " f may e 1rs�" 20. Run cement bond log/GR/CCL. Cf -- ----� � �c kA is 21. RU tubing conveyed perforating equipment and RIH with gtms 22. Place guns on depth and fire same 23. POOH with guns and LD same 24. Pick up and run in hole with the lower tubing frac./production string. 25. Run Upper completion per completion schematic.(Latch into anchor, shear PBR,space out,etc.) 26. Land tubing and test tubing hanger. 27. Test inner annulus to 2500 psi for 30 minut s.(Note: This will test tubing integrity.) 28. Pressure up on IA to shear SOV at 3000 psi./ OR1GNAL S 29. Set BPV and ND BOP. 30. Nipple up tree and test same. u, • 31. RDMO. Sint N j2st, Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Class II waste fluids will be sent to the class II disposal well at BRWD. Fluids will then be centrifuged to separate out solids greater than 10 microns. All Class II fluids will be transported in the Drilling vacuum truck to prevent mixing of Class I fluids. Class I fluids will be sent to the class I disposal well BRU 232-09 using only the Production vacuum truck. Drill cuttings and solids will be deposited at the Beluga Solid Waste Disposal Cell#5. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL • • { ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 242-04 BRU 242-04 Plan: BRU 242-04 (wp13) Standard Proposal Report 02 February, 2012 HALLIBURTON Sperry Drilling Services NIA 11 L 1 i HALLIBURTON Pro] ct: Beluga River WELL DETAILS: Plan:B1 l 242-04 NAD 1927(NADCON CONUS) Alaska Zone 04 Sperry Drilling Services Site: Beluga River Ground Level: 92.14 Well: Plan: BRU 242-04 +N/-S+E/-W Northing Fasting Latittude Longitude Slot Wellbore: BRU 242-04 0.00 0.00 2619715.42 315291.27 61°9'58.660N 151°r 45.874 W Plan: BRU 242-04(wp13) REFERENCE INFORMATION 0 Co-ordinate(N/E)Reference:Well Plan:BRU 242-04,True North I. SHL:201'FNL,368'FEL-Sec4-T12N-R1OW Vertical(TVD)Reference:Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) Measured Depth Reference: Plan:- 16"Conductor Casing Calculation Method:Minimum Curvature @ 110.64ft(Arctic Fox) 400 D° Start Build 2.00 FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 2930.64 2820.00 3431.70 BRWD-1 Injection Zone 5° ----Start DLS 4.00 TFO-13.82 3140.64 3030.00 3647.57 Sterling A- 800 3342.64 3232.00 3852.68 Sterling B- 3487.64 3377.00 3999.92 Sterling C 10p0 3645.64 3535.00 4160.38 Beluga D. 3915.64 3805.00 4434.51 Beluga E - 5 4250.64 4140.00 4774.69 Beluga F - 1200 2 4810.64 4700.00 5343.37 Beluga G Start 1168.39 hold at 1626.27 MD 5200.64 5090.00 5739.42 Beluga H 95 5968.64 5858.00 6519.37 Beluga I 6485.64 6375.00 7044.46 Beluga J(Beluga I base) 1600 000 CASING DETAILS '1 MD TVD TVDSS Name Size Hole Size 1x0 88.00 88.00 -22.6416"Conductor Casing 16 20 2000 3373.67 2875.64 2765.009 5/8"Surface Casing 9-5/8 12-1/4 7247.58 6685.64 6575.00 7"Production Casing 7 8-3/4 Start DLS 4.00 TFO-179.87 2400 ,500 2800 9 5/8"Surface Casing 5 9 5/8"Casing @ 3374'MD,2876'TVD:1657'FNL,665'FEL-Sec4-T12N-R1OW = BRWD-1 Injection Zone- ,..,-- ° 15 Start 375.71 hold at 3617.10 MD 0 3200 -Sterling A co 10° t - -Sterling B- BRU 242-04wp13 Sterling C cp_ Sterling O - ::0 Top Sterling C @ 3993'MD,3481'TVD:1783'FNL,688'FEL-Sec4-T12N-R10W 0 3600 m - Beluga D ---Top-Top Beluga D @ 4160'MD,3646'TVD:1811'FNL,694'FEL-Sec4-T12N-R1OW U_ j Beluga E N 4000 2 H Beluga F 4400 5000 4800 - Beluga G 5200 Beluga H 6000 5600 6000 Beluga t- _. 6400 BRU 242-04wp13 Beluga J_ 7p00 Beluga J(Beluga I base) 7"Production Casing--' •7-2.48 6800 TD at 7248'MD 6686'TVD:2340'FNL,792'FEL-Sec4-T12N-R1OW BRtJ 242-04 1wP131 I I I i I i i I l I l l l i I I I i I I i t I l I I I I i I I I i i I t I I I I i l I I I I i i i I I I I I I i l I I I I i l I I I i i t I i l I -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 Vertical Section at 191.13° (800 ft/in) '1.'' ConocoPhillips Alaska �I....f`� r".1 IGNAL HALLIBURTON Project: Beluga River 411)WELL DETAILS: Plan:BRU 242-04 Sperry Drilling Services Site: Beluga River Services Ground Level: 92.14 Well: Plan: BRU 242-04 +N/-S+F/-W Northing Easting Latittude Longitude Slot Wellbore: BRU 242-04 0.00 0.00 2619715.42 315291.27 61°9'58.660N 151°2'45.874W Plan: BRU 242-04 (wp13) REFERENCE INFORMATION Co-ordinate(WE)Reference:Well Plan:BRU 242-04,True North Vertical(TVD)Reference:Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) Measured Depth Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) Calculation Method:Minimum Curvature BRU 242-04 (wp13) DDI = 5.297 16"Conductor Casing 0-- - - - - ----__ SIlL:201'FNL,368'FEL-Sec4-T12N-RIOW -50�' Start Build 2.00 1000 Start DLS 4.00 TFO-13.82 1250 -250— 1500 Start 1168.39 hold at 1626.27 MD -500— 1750 -750— 2000 CASING DETAILS: BRU 242-04(wp13) MD TVD TVDSS Name Size Hole Size 0-1000— 88.00 88.00 -22.64 16"Conductor Casing 16 20 c 3373.67 2875.64 2765.00 9 5/8"Surface Casing 9-5/8 12-1/4 en 2250 7247.58 6685.64 6575.00 7"Production Casing 7 8-3/4 - 0 -Start DLS 4.00 TFO-179.87 1250— 2500 o - rn 9 5/8"Surface Casing 2750 IBRU 242-04wp13 Sterling -1500 DD Polygon 95%con'. 9 5/8"Casing @ 3374'MD,2876'TVD:1657'FNL,665'FEL-Sec4-T12N-RI OW 3250 Start 375.71 hold at 3617.10 MD -- Top Sterling C @ 3993'MD,3481'TVD:1783'FNL,688'FEL-Sec4-Tl2N-RIOW 3750 - ---'---- Top Beluga D @ 4160'MD,3646 TVD:1811'FNL,694'FEL-Sec4-TI2N-RIOW -1750— 4750 5250 BRU 242-04wp13 Beluga 1 -2000— I DD Polygon 95%con 6250 7"Production Casin_• TD at 7248'MD 6686'TVD:2340'FNL,792'FEL-Sec4-T12N-RIOW M Azimuths to True North Magnetic North:16.10° -2250— Magnetic Field BRU�2-04(wP13) Strength:54997.0snT Dip Angle:72.91° Date:2/11/2009 Model:BGGM2007 1 1 1 1 I 1 I 1 1 1 1 I -1000 -750 -500 -250 0 250 500 750 1000 West(-)/East(+)(300 fl/in) ConocoPhillips Alaska • III Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db ocal Co-ordinate Reference: Well Plan:BRU 242-04 Company: ConocoPhillips(Alaska)Inc.-Expl TVD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) Project: Beluga River MD Reference: • Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) .• Site: , Beluga River North Reference: True Well: Plan:BRU 242-04 Survey Calculation Method: Minimum Curvature Wellbore: BRU 242-04 Design: BRU 242-04(wp13) Project Beluga River,Alaska,USA a..apanx a.s: 4 V,I.X:m.,a4.071.21cr; wiftisil Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Beluga River W Site Position: Northing: 2,630,909.88ft Latitude: 61°11'51.001 N From: Map Easting: 329,245.55ft Longitude: 150°58'4.800 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.85° Well Plan:BRU 242-04 Well Position +N/-S 0.00 ft Northing: 2,619,715.42 ft • Latitude: 61°9'58.660 N +E/-W 0.00 ft Easting: 315,291.27 ft Longitude: 151°2'45.874 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.14 ft . Wellbore BRU 242-04 Magnetics Model Name' amp e'a a 'eclination Dip Angle Field Strength (o) (0) (nT) BGGM2007 2/11/2009 16.10 72.91 54,997 Design BRU 242-04(wp13) Audit Notes: Version: Phase: PLAN Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-S +E/-W -• Direction (ft) (ft) ,.(ft) (0) L 18.56 Q00 0.00 191.13 Plan Sections „.t.{c",°;figs. P ".. ... Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N!S , +E/-W Rate Rate Rate Tool Face (ft)" (0) () (ft) t (ft) (ft) (°I100ft) 0100ft) (0/100ft) (°) W 18.50 0.00 0.00 18.50 -92.14 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 289.36 0.00 0.00 0.00 0.00 0.00 0.00 700.00 6.00 203.11 699.45 588.81 -14.43 -6.16 2.00 2.00 0.00 203.11 1,626.27 42.90 190.90 1,528.42 1,417.78 -381.41 -87.62 4.00 3.98 -1.32 -13.83 2,794.66 42.90 190.90 2,384.35 2,273.71 -1,162.37 -237.98 0.00 0.00 0.00 0.00 3,617.10 10.00 190.50 3,110.64 3,000.00 -1,517.25 -305.79 4.00 -4.00 -0.05 -179.87 3,992.81 10.00 190.50 3,480.64 3,370.00 -1,581.40 -317.68 0.00 0.00 0.00 0.00 7,044.46 10.06 190.45 6,485.64 6,375.00 -2,104.05 -414.31 0.00 0.00 0.00 -8.20 7,247.58 10.06 190.45 6,685.64 6,575.00 -2,138.95 -420.75 0.00 0.00 0.00 0.00 2/2/2012 2:34:01 PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL • 0 Halliburton -Sperry HALLIBURTON Standard Proposal Report a a se _ EDM 2003.16 Single User Db ( o •ix n x Well Plan:BRU 242-04 • ConocoPhillips(Alaska)Inc.-Expl ; efe? tt e 'Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) ' ."".;'„Beluga River MD Refe: tics ',: .' Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) Aftitlikk Beluga River NorthRe erenece:'. * True e I g, Plan:BRU 242-04 Survey Calculation Methods M.,=:R Minimum Curvature Web BRU 242-04 De •`n BRU 242-04(wp13) _.e , .�.�....,.....��...., Planned Survey !-„:1?:,',;.:1:ifi'f:''.. ..-,4,..",i.,..,. ,,,,,,,...„.,',,r,F.--,-sf,,,J.':-,, ,,,,-,y:-,F ,,.:,„,.--z :,----,,---,,-,;1:--,,'-, .'.-,'''.': ,,,-47,,-‘,,--2:1:1-i4."';',,,41'-erp',,,',;;,,c4I-,3,3:',V-'4,;,.....1.V";,;',1,,' '";.,pii;';',Tri.-.;,i":1,-IV- I . Measured ' .. : - . � Depth ,Incllinatio "+, •, ) l * i 0-r e .. 44, ' s (n) ; ft 2 r ,, 18.50 0.00 0.00 18.50 -92.14 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 18.51 0.00 0.00 18.51 -92.13 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 SHL:201'FNL,368'FEL-Sec4-T12N-R10W 88.00 0.00 0.00 88.00 -22.64 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 16"Conductor Casing 100.00 0.00 0.00 100.00 -10.64 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 200.00 0.00 0.00 200.00 89.36 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 300.00 0.00 0.00 300.00 189.36 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 400.00 0.00 0.00 400.00 289.36 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 Start Build 2.00 500.00 2.00 203.11 499.98 389.34 -1.61 -0.68 2,619,713.82 315,290.56 2.00 1.71 600.00 4.00 203.11 599.84 489.20 -6.42 -2.74 2,619,709.04 315,288.43 2.00 6.83 700.00 6.00 203.11 699.45 588.81 -14.43 -6.16 2,619,701.08 315,284.88 2.00 15.35 Start DLS 4.00 TFO-13.82 800.00 9.93 197.56 798.47 687.83 -27.47 -10.81 2,619,688.13 315,280.02 4.00 29.04 900.00 13.90 195.15 896.30 785.66 -47.29 -16.56 2,619,668.40 315,273.96 4.00 49.60 1,000.00 17.88 193.80 992.46 881.82 -73.80 -23.36 2,619,642.00 315,266.73 4.00 76.93 1,100.00 21.87 192.93 1,086.48 975.84 -106.88 -31.19 2,619,609.05 315,258.37 4.00 110.89 1,200.00 25.86 192.31 1,177.91 1,067.27 -146.36 -40.02 2,619,569.72 315,248.92 4.00 151.34 1,300.00 29.86 191.85 1,266.30 1,155.66 -192.06 -49.78 2,619,524.19 315,238.43 4.00 198.05 1,400.00 33.85 191.49 1,351.22 1,240.58 -243.73 -60.45 2,619,472.70 315,226.94 4.00 250.82 1,500.00 37.85 191.20 1,432.26 1,321.62 -301.15 -71.96 2,619,415.48 315,214.51 4.00 309.38 1,600.00 41.85 190.96 1,509.01 1,398.37 -364.02 -84.27 2,619,352.81 315,201.20 4.00 373.44 1,626.27 42.90 190.90 1,528.42 1,417.78 -381.40 -87.62 2,619,335.49 315,197.57 4.00 391.14 Start 1168.39 hold at 1626.27 MD 1,700.00 42.90 190.90 1,582.43 1,471.79 -430.69 -97.11 2,619,286.37 315,187.29 0.00 441.33 1,800.00 42.90 190.90 1,655.69 1,545.05 -497.53 -109.98 2,619,219.74 315,173.36 0.00 509.40 1,900.00 42.90 190.90 1,728.95 1,618.31 -564.37 -122.85 2,619,153.12 315,159.42 0.00 577.47 2,000.00 42.90 190.90 1,802.21 1,691.57 -631.21 -135.72 2,619,086.50 315,145.49 0.00 645.54 2,100.00 42.90 190.90 1,875.46 1,764.82 -698.05 -148.59 2,619,019.87 315,131.55 0.00 713.60 2,200.00 42.90 190.90 1,948.72 1,838.08 -764.89 -161.46 2,618,953.25 315,117.61 0.00 781.67 2,300.00 42.90 190.90 2,021.98 1,911.34 -831.73 -174.32 2,618,886.63 315,103.68 0.00 849.74 2,400.00 42.90 190.90 2,095.23 1,984.59 -898.57 -187.19 2,618,820.01 315,089.74 0.00 917.81 2,500.00 42.90 190.90 2,168.49 2,057.85 -965.42 -200.06 2,618,753.38 315,075.81 0.00 985.88 2,600.00 42.90 190.90 2,241.75 2,131.11 -1,032.26 -212.93 2,618,686.76 315,061.87 0.00 1,053.95 2,700.00 42.90 190.90 2,315.01 2,204.37 -1,099.10 -225.80 2,618,620.14 315,047.94 0.00 1,122.01 2,794.66 42.90 190.90 2,384.35 2,273.71 -1,162.37 -237.98 2,618,557.07 315,034.74 0.00 1,186.45 Start DLS 4.00 TFO-179.87 2,800.00 42.68 190.90 2,388.27 2,277.63 -1,165.93 -238.67 2,618,553.52 315,034.00 4.00 1,190.08 2,900.00 38.68 190.88 2,464.09 2,353.45 -1,229.93 -250.98 2,618,489.73 315,020.67 4.00 1,255.25 3,000.00 34.68 190.87 2,544.26 2,433.62 -1,288.59 -262.25 2,618,431.27 315,008.46 4.00 1,314.98 3,100.00 30.68 190.85 2,628.41 2,517.77 -1,341.61 -272.42 2,618,378.41 314,997.45 4.00 1,368.97 3,200.00 26.68 190.82 2,716.12 2,605.48 -1,388.75 -281.44 2,618,331.43 314,987.68 4.00 1,416.95 3,300.00 22.68 190.78 2,806.97 2,696.33 -1,429.76 -289.27 2,618,290.56 314,979.20 4.00 1,458.71 2/2/2012 2:34:01 PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL • 0 Halliburton -Sperry FlALLIBUR1 DN Standard Proposal Report a'a8e EDM 2003 16 Single User Db e 1 Well Plan:BRU 242-04 .a k ConocoPhillips(Alaska)Inc.-Expi tr Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) o - r Beluga River ++ Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) 3 k e: Beluga River i True v.klit:i Plan:BRU 242-04 k, u t Minimum Curvature e 1,!...1,,,t,' BRU 242-04 ,e n " BRU 242-04(wp13) Planned uryey , ...""• '*',, ' a s § A..,',.s KK $x fig,. } Measured Vertical Depth Inclination Azimuth Depth TVDss +NI-5 +E/ 1 a 1 "�a v , on ' (ft) (^) (1 (ft) ft ', (ft) ({t) ft 4 $a1 3,373.67 19.74 190.75 2,875.64 2,765.00 -1,455.94 -294.24 2,618,264.46 314,973.80 4.00 1,485.36 9 5/8"Casing @ 3374'MD,2876'TVD:1657'FNL,665'FEL-Sec4-T12N-R19W-9 5/8"Surface Casing 3,400.00 18.68 190.74 2,900.50 2,789.86 -1,464.45 -295.86 2,618,255.97 314,972.05 4.00 1,494.02 3,431.70 17.42 190.72 2,930.64 2,820.00 -1,474.10 -297.69 2,618,246.36 314,970.07 4.00 1,503.84 BRWD-1 Injection Zone 3,500.00 14.68 190.66 2,996.27 2,885.63 -1,492.66 -301.19 2,618,227.86 314,966.27 4.00 1,522.72 3,600.00 10.68 190.53 3,093.81 2,983.17 -1,514.23 -305.23 2,618,206.35 314,961.88 4.00 1,544.67 3,617.10 10.00 190.50 3,110.64 3,000.00 -1,517.25 -305.79 2,618,203.34 314,961.27 4.00 1,547.74 Start 375.71 hold at 3617.10 MD 3,647.57 10.00 190.50 3,140.64 3,030.00 -1,522.45 -306.75 2,618,198.16 314,960.23 0.00 1,553.03 Sterling A 3,700.00 10.00 190.50 3,192.28 3,081.64 -1,531.41 -308.41 2,618,189.23 314,958.43 0.00 1,562.14 3,800.00 10.00 190.50 3,290.76 3,180.12 -1,548.48 -311.58 2,618,172.21 314,954.99 0.00 1,579.50 3,852.68 10.00 190.50 3,342.64 3,232.00 -1,557.48 -313.25 2,618,163.25 314,953.18 0.00 1,588.65 Sterling B 3,900.00 10.00 190.50 3,389.24 3,278.60 -1,565.55 -314.74 2,618,155.19 314,951.55 0.00 1,596.87 3,992.81 10.00 190.50 3,480.64 3,370.00 -1,581.40 -317.68 2,618,139.40 314,948.36 0.00 1,612.98 Top Sterling C @ 3993'MD,3481'TVD:1783'FNL,688'FEL-Sec4-T12N-R10W-BRU 242-04wp13 Sterling C 3,999.92 10.00 190.50 3,487.64 3,377.00 -1,582.62 -317.90 2,618,138.19 314,948.12 0.00 1,614.22 Sterling C 4,000.00 10.00 190.50 3,487.72 3,377.08 -1,582.63 -317.91 2,618,138.17 314,948.11 0.18 1,614.23 4,100.00 10.00 190.50 3,586.20 3,475.56 -1,599.70 -321.07 2,618,121.15 314,944.68 0.00 1,631.60 4,160.32 10.00 190.50 3,645.60 3,534.96 -1,610.01 -322.98 2,618,110.88 314,942.60 0.00 1,642.07 Top Beluga D @ 4160'MD,3646'ND:1811'FNL,694'FEL-Sec4-T12N-R10W 4,160.34 9.80 190.67 3,645.64 3,535.00 -1,609.90 -322.98 2,618,110.98 314,942.61 1,005.03 1,641.97 Beluga D 4,200.00 10.00 190.50 3,684.68 3,574.04 -1,616.78 -324.24 2,618,104.12 314,941.24 0.52 1,648.96 4,300.00 10.01 190.49 3,783.16 3,672.52 -1,633.87 -327.40 2,618,087.09 314,937.80 0.00 1,666.34 4,400.00 10.01 190.49 3,881.64 3,771.00 -1,650.95 -330.57 2,618,070.06 314,934.36 0.00 1,683.71 4,434.56 10.49 190.11 3,915.64 3,805.00 -1,657.00 -331.67 2,618,064.03 314,933.17 1.41 1,689.86 Beluga E 4,500.00 10.01 190.49 3,980.11 3,869.47 -1,668.04 -333.73 2,618,053.03 314,930.93 0.74 1,701.09 4,600.00 10.01 190.49 4,078.59 3,967.95 -1,685.14 -336.90 2,618,035.99 314,927.49 0.00 1,718.48 4,700.00 10.01 190.49 4,177.07 4,066.43 -1,702.23 -340.06 2,618,018.94 314,924.05 0.00 1,735.86 4,774.69 9.85 190.62 4,250.64 4,140.00 -1,714.90 -342.42 2,618,006.32 314,921.49 0.22 1,748.74 Beluga F 4,800.00 10.02 190.49 4,275.54 4,164.90 -1,719.33 -343.23 2,618,001.90 314,920.61 0.66 1,753.25 4,900.00 10.02 190.49 4,374.02 4,263.38 -1,736.44 -346.39 2,617,984.85 314,917.17 0.00 1,770.64 5,000.00 10.02 190.48 4,472.50 4,361.86 -1,753.54 -349.56 2,617,967.79 314,913.74 0.00 1,788.04 5,100.00 10.02 190.48 4,570.97 4,460.33 -1,770.66 -352.72 2,617,950.74 314,910.30 0.00 1,805.44 5,200.00 10.02 190.48 4,669.44 4,558.80 -1,787.77 -355.89 2,617,933.68 314,906.86 0.00 1,822.84 5,300.00 10.03 190.48 4,767.92 4,657.28 -1,804.89 -359.06 2,617,916.61 314,903.42 0.00 1,840.25 5,343.41 10.41 190.17 4,810.64 4,700.00 -1,812.46 -360.44 2,617,909.06 314,901.92 0.90 1,847.95 Beluga G 5,400.00 10.03 190.48 4,866.39 4,755.75 -1,822.01 -362.22 2,617,899.55 314,899.98 0.68 1,857.66 2/2/2012 2:34:01 PM Page 4 COMPASS 2003.16 Build 69 OR1GNtL • 0 Halliburton -Sperry HALLIBURTON Standard Proposal Report DM 2003.16 Single User Db r' a e e Well Plan:BRU 242-04 I''''I:m•a ConocoPhillips(Alaska)Inc.-Expl e n Plan:242-04(18.5+82.14)@ 110.641t(Arctic Fox) Beluga River 4-`-'1Nf)�a -ie aii.,r s"- _, Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) ate " ,Beluga River e hce True 3 t: "' rY Plan:BRU 242-04 r.,e4 e a i• a Minimum Curvature e ib' ,, BRU 242-04 � ' s es n BRU 242 04(wp13) .-3• .°411---:j n ' h TVDss +N/S + : ft) 11 �} ft (ft) (ft) r 2 10.03 190.48 4,964.86 4,854.22 -1,839.13 -365.39 2,617,882.48 314,896.54 0.00 1,875.07 5,600.00 10.03 190.47 5,063.33 4,952.69 1,856.26 -368.56 2,617,865.40 314,893.10 0.00 1,892.49 5,700.00 10.03 190.47 5,161.80 5,051.16 -1,873.39 -371.72 2,617,848.32 314,889.66 0.00 1,909.91 5,739.42 9.72 190.74 5,200.64 5,090.00 -1,880.04 -372.97 2,617,841.70 314,888.31 0.79 1,916.68 Beluga H 5,800.00 10.04 190.47 5,260.27 5,149.63 -1,890.53 -374.89 2,617,831.24 314,886.22 0.52 1,927.34 5,900.00 10.04 190.47 5,358.74 5,248.10 -1,907.67 -378.06 2,617,814.16 314,882.78 0.00 1,944.76 6,000.00 10.04 190.47 5,457.21 5,346.57 -1,924.81 -381.22 2,617,797.07 314,879.34 0.00 1,962.19 6,100.00 10.04 190.47 5,555.68 5,445.04 1,941.95 384.39 2,617,779.98 314,875.90 0.00 1,979.63 6,200.00 10.04 190.46 5,654.15 5,543.51 1,959.10 387.56 2,617,762.88 314,872.46 0.00 1,997.07 6,300.00 10.05 190.46 5,752.61 5,641.97 -1,976.25 -390.73 2,617,745.79 314,869.01 0.00 2,014.51 6,400.00 10.05 190.46 5,851.08 5,740.44 1993.41 -393.89 2,617,728.68 314,865.57 0.00 2,031.95 6,500.00 10.05 190.46 5,949.55 5,838.91 -2,,010.57 -397.06 2,617,711.58 314,862.13 0.00 2,049.40 6,519.42 10.91 189.81 5,968.64 5,858.00 -2,014.05 -397.68 2,617,708.11 314,861.46 4.47 2,052.93 Beluga 6,600.00 10.05 190.46 6,048.01 5,937.37 -2,027.73 -400.23 2,617,694.47 314,858.69 1.08 2,066.85 6,700.00 10.05 190.46 6,146.48 6,035.84 -2,044.90 -403.40 2,617,677.36 314,855.25 0.00 2,084.31 6,800.00 10.06 190.45 6,244.94 6,134.30 -2,062.07 -406.56 2,617,660.24 314,851.81 0.00 2,101.76 6,900.00 10.06 190.45 6,343.40 6,232.76 -2,079.24 -409.73 2,617,643.12 314,848.36 0.00 2,119.23 7,000.00 10.06 190.45 6,441.87 6,331.23 -2,096.42 -412.90 2,617,626.00 314,844.92 0.00 2,136.69 7,044.46 10.06 190.45 6,485.64 6,375.00 -2,104.05 -414.31 2,617,618.39 314,843.39 0.00 2,144.46 Beluga J(Beluga I base)-BRU 242-04wp13 Beluga J 7,100.00 10.06 190.45 6,540.33 6,429.69 -2,113.60 -416.07 2,617,608.88 314,841.48 0.00 2,154.16 7,200.00 10.06 190.45 6,638.79 6,528.15 -2,130.77 -419.24 2,617,591.75 314,838.04 0.00 2,171.63 7,247.58 10.06 190.45 6,685.64- 6,575.00 -2,138.95 -420.75 • 2,617,583.60 314,836.40 0.00 2,179.94 TD at 7248'MD 6686'TVD:2340'FNL,792'FEL-Sec4-T12N-R1OW-7"Production Casing Targets , w. Target Name ,, hit/miss target Y Dip Angle Dip Dir. TVD +N/-S 1 +E/-W m --Shape c. � (0) (0) (ft) ft BRU 242-04wp13 Beluga J 0.00 0.00 6,485.64 -2,104.05 -414.31 2,617,618.39 314,843.39 -plan hits target center -Circle(radius 150.00) BRU 242-04wp13 Sterling C 0.00 0.00 3,480.64 -1,581.40 -317.68 2,618,139.40 314,948.36 -plan hits target center -Circle(radius 150.00) I 2/2/2012 2:34:01 PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL 0 • Halliburton -Sperry HALLIBURTON Standard Proposal Report is alias EDM 2003.16 Single User Db Well Plan:BRU 242-04 mpa ConocoPhillips(Alaska)Inc. Expl .j� Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) project „': Beluga River . A Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) lSite: i Beluga River ,a True Well: Plan:BRU 242-04 `01 , Minimum Curvature Wellborn'1 BRU 242-04 Design: ; BRU 242 04(wp13) .fix .,. ,. .,. , . .:. ,., ... .,. 88.00 88.00 16"Conductor Casing 16 20 3,373.67 2,875.64 9 5/8"Surface Casing 9-5/8 12-1/4 7,247.58 6,685.64 7"Production Casing 7 8-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS _; Direction �" = Dip (ft) (ft) ft Name . „ . .w. .. (`) (') 5,343.37 4,810.64 Beluga G 0.00 4,434.51 3,915.64 Beluga E 0.00 7,044.46 6,485.64 Beluga J(Beluga I base) 0.00 3,647.57 3,140.64 Sterling A 0.00 3,852.68 3,342.64 Sterling B 0.00 3,999.92 3,487.64 Sterling C 0.00 4,160.38 3,645.64 Beluga D 0.00 3,431.70 2,930.64 BRWD-1 Injection Zone 0.00 6,519.37 5,968.64 Beluga I 0.00 4,774.69 4,250.64 Beluga F 0.00 5,739.42 5,200.64 Beluga H 0.00 Plan Annotations ,, ,u: _.: x.,,-: .s : ',sue r stt. 4 Ss ,3- - re e I0 x ft ft (�)":_., (it). Comment ? a . 18.51 18.51 0.00 0.00 SHL:201'FNL,368'FEL-Sec4-T12N-R10W 400.00 400.00 0.00 0.00 Start Build 2.00 700.00 699.45 -14.43 -6.16 Start DLS 4.00 TFO-13.82 1,626.27 1,528.42 -381.40 -87.62 Start 1168.39 hold at 1626.27 MD 2,794.66 2,384.35 -1,162.37 -237.98 Start DLS 4.00 TFO-179.87 3,373.67 2,875.64 -1,455.94 -294.24 9 5/8"Casing @ 3374'MD,2876'TVD:1657'FNL,665'FEL-Sec4-T12N-R1OW 3,617.10 3,110.64 -1,517.25 -305.79 Start 375.71 hold at 3617.10 MD 3,992.81 3,480.64 -1,581.40 -317.68 Top Sterling C @ 3993'MD,3481'TVD:1783'FNL,688'FEL-Sec4-T12N-R1OW 4,160.32 3,645.60 -1,610.01 -322.98 Top Beluga D @ 4160'MD,3646'TVD:1811'FNL,694'FEL-Sec4-T12N-R1OW 7,247.58 6,685.64 -2,138.95 -420.75 TD at 7248'MD 6686'TVD:2340'FNL,792'FEL-Sec4-T12N-R1OW 2/2/2012 2:34:01 PM Page 6 COMPASS 2003.16 Build 69 ORIGINAL 4. ConocoPhillips (Alaska) Inc. -Expl Beluga River Beluga River Plan: BRU 242-04 BRU 242-04 BRU 242-04 (wp13) III p k' ry Sperry Drilling Services Clearance Summary :` '' Anticollision Report 02 February, 2012 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Beluga River-Plan:BRU 242-04-BRU 242-04-BRU 242-04(wp13) Well Coordinates: 2,619,476.00 N,1,455,318.00 E (61°09'56.65"N,151°02'53.91"W) Datum Height: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox) Scan Range: 0.00 to 7,247.58 ft.Measured Depth. Scan Radius is 922.91 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON A. Sperry Drilling Services 'll1=11111111■11111V 1111111=11 SURVEY PROGRAM ConocoPhillips(Alaska)Inc.-Expl I- ILL • Date:2012-02-02T00:00:00 Validated:Yes Version: Engineering Interpolation Method: MD,interval:25.00 Calculation Method: Minimum Curvature Depth Range From: 18.50 To 7247.58 Error System: ISCWSA Centre Distance:922.91 Depth From Depth To Survey/Plan Tool Scan Method: Tray.Cylinder North Reference: Plan:BRU 242-04(wp13)(Plan:BRU 242-04/BRU 242-0, 18.50 7247.58 BRU 242-04(wp13)(BRU 242-04) MWD+SCC+SAG Error Surface: Elliptical Conic GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Warning Method: Rules Based BRU 224-34 0 From Colour To MD 3i 330 ► �-` 30 19 259 0 40 MIIINISIS 401 *4P0.41114144, 259 509 330 30 '" �' 509 759 Ill l �� `,, Aa ' 759 1009 in 300 ''' * o4 , oNz`e 60 1009 1259 .,�� S,, le 011 i 1 ' �' \ �� 1259 1509 300 60 �~' 1509 1759 � `1 1759 2009 / 11111' 0 mitt 1� 2009 2509 2509 3009 270 �� 90 z7o Om"' - 90 3009 3509 3509 4009 %V. Yx 4009 4509 rwl, 2 _ ' ,,4509 5009 �; 240 � �� 120 5009 6009 I 6009 7009 , 0 2ao Ilk‘ill‘ ''' 1zo 7009 8009 ,` <. 8009 9009 210 150 1...' ` ` 9009 10009 180 7,4 ` - 10009 12009 210 31r ' 150 12009 14009 401 14009 16009 Travelling Cylinder Azimuth(TFO+AZI)[°J vs Centre to Centre Separation[50 ft/in] 180 i ConocoPhillips(Alaska)Inc.-Expl HALLIBURTON Beluga River Anticollision Report for Plan: BRU 242-04 - BRU 242-04 (wp13) Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Beluga River-Plan:BRU 242-04-BRU 242-04-BRU 242-04(wp13) Scan Range: 0.00 to 7,247.58 ft.Measured Depth. Scan Radius is 922.91 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Separation Warning Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name-Wellbore Name-Design (ft) (ft) (ft) (ft) ft Beluga River BRU 211-03-BRU 211-03-BRU 211-03 282.63 209.77 282.63 204.30 275.00 38.380 Centre Distance Pass-Major Risk • BRU 211-03-BRU 211-03-BRU 211-03 528.89 211.55 528.89 201.49 525.00 21.028 Clearance Factor Pass-Major Risk BRU 224-34-BRU 224-34-BRU 224-34 382.64 109.77 382.64 103.76 375.00 18.271 Centre Distance Pass-Major Risk BRU 224-34-BRU 224-34-BRU 224-34 676.96 112.02 676.96 101.58 675.00 10.737 Clearance Factor Pass-Major Risk G..) Survey tool program ° From To Survey/Plan Survey Tool (ft) (ft) t 18.50 7,247.58 BRU 242-04(wp13) MWD+SCC+SAG Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). • All station coordinates were calculated using the Minimum Curvature method. 02 February,2012 - 10:09 Page 2 of 4 COMPASS ConocoPhillips (Alaska) Inc.-Expl HALLIBURTON Beluga River Anticollision Report for Plan: BRU 242-04 - BRU 242-04 (wp13) Direction and Coordinates are relative to Grid North Reference. Vertical Depths are relative to Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox). Northing and Fasting are relative to Plan:BRU 242-04. Coordinate System is US State Plane 1983,Alaska Zone 4. Central Meridian is-150.00°,Grid Convergence at Surface is: -0.92°. Ladder Plot • C . I 900 I o I . o co � . O ° I . co 600 LEGEND a . . I Cl)C ' BRU 211-03,BRU 211-03,BRU 211-03 VO ----- N BRU 224-34,BRU 224-34,BRU 224-34 V0 �--� L .� -9- BRU 242-04(wp13) N o 300 ' 2 c I • Ct I . 0 0 350 700 1050 1400 1750 Measured Depth (350 ft/in) 02 February,2012 - 10:09 Page 3 of 4 COMPASS ConocoPhillips(Alaska)Inc.-Expl HALLIBURTON Beluga River Anticollision Report for Plan: BRU 242-04 - BRU 242-04 (wp13) Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 10.00— 8.75— • III ! ^ 7.50— c - 0 Lo. .-- 625 - - LEGEND as cO 5.00— - - - -_._ BRU 211-03,BRU 211-03,BRU 211-03 VO G) m _ $ BRU 224-34,BRU 224-34,BRU 224-34 VO co $ BRU 242-04(wp13) N 3.75- 2.50- 125— i 0.00 i i i l l I I I I I I I I I I I I II ; 11 1 ! ii Hi Ili II II III I I I I I I I IIIIIIIIH 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 Measured Depth(300 ft/in) 02 February,2012 - 10:09 Page 4 of 4 COMPASS . • BRU 242-04 Drilling Hazards Summary (To be posted in Rig Floor Doghouse prior to spud) Surface: 12-1/4" Hole with 9-5/8" Casing Event Risk Level Mitigation Strategy Lost Circulation Medium Reduced pump rates, control ROP and running speeds, mud rheology, lost circulation material, use of low density cement slurries. Clay Balling Medium Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Gas Hydrates Low Monitor well, increased mud weight, managed fluid rheologies, decreased circulating times, controlled drilling rates, low mud temperatures Abnormal Pressure in Low / Diverter drills, increased mud weight. Offset Surface Formations drilling does not indicate abnormal pressures in the surface hole. Production: 8-3/4" Hole with 7" Casing Event Risk Level Mitigation Strategy Lost circulation High Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, Pre-planned LCM pills, lost circulation material. Sloughing Shale, Tight High Increased mud density to control the shale's, Hole manage fluid composition according to plan, control running speeds and ECD's, sweeps Tight hole in coals Medium Control drilling, mud logs, crew awareness Directional Control Medium BHA design, geologic review and advisement of potential slump blocks. Hole swabbing on trips Low Reduced trip speeds, mud properties, proper hole filling, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low Well control drills, increased mud weight, offset Pressure well data does not indicate abnormal pressures in the area. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices . • I 1 l 1 21-1/4" 2000 PSI 1m m1 iI, ill IlL 12"ANSI 150 63.38" 35.06" I 1 RIG MAT 1 GROUND LEVEL/TOP OF CELLAR 1 6.00" 1 i 15.50" , 38.56" I 30.00" 1 ,I 49.50" 48.56" G96.00" I 'I ( - 20"CASING CUT—OFF 1111 ;,` J;1 46.50" R' j .1 20"VG—LOC !�I I ,10' i NN I 1 I 30.31" I11 1 f J I j 'I-----20 CONDUCTOR / 9-5/8" 40#L80 CASING �/ PROPRIETARY NOTICE vetcog ray TM The information contained hereon is the confidential property of vetcogroy and its affiliates. It is to be used only 21-1/4" DRILLING RISER ASSEMBLY ARRANGED FOR for the benefit of ray, and shall not be reproduced or used for USE OVER 20" CASING WITH LANDING RING any other purpose without written consent of vetcogray. WITH 20" QUICK CONNECTIONS AND 12" ANSI CLASS 150 OUTLET DRAM OM DATE G RICE 15 APR 2000 RETRIED eIr DAIS X 'NC APPRawD sr, DATE CUSTOMER n w SP-695$-1 x � � CONOCO PHIWPS/ARCTIC FOX/BELUGA PROJECT AU.oRRnsa ARE APPROXIMATE I 51FFr1 0E1 24.69- • • • ilEki •.�■ y1C. w MiINr • 18.00• t , 1.38' RIG MAT I 41:1 7.63' uw�-�=1 ,!'■ � 6.00' GROUNO`LEVEL A TOP OF - �r.i�� 14.83- 1 11111 - IBM j 1 i �I� C" � 30.00- 49.50" 1 uii I I in / in' nor 96.00• / Al - 1 111%, 20"CASING CUT-OFF ;` .4, 46.50" fil I I/ ( II f 20 CONDUCTOR 1 9-5/8' 40/L80 CASING /// 1I 7 26#L80 CASING PROPRIETARY NOTICE vetcog ray The Information contained hereon is the confidential property of vetcogray and its affiliates. It is to be used only M8-230 MULTIBOWL SYSTEM for the benefit of vetcogray, and shall not be reproduced or used for ELEVATION VIEW OF 7"LANDING JOINT TO GROUND LEVEL any other purpose without written WITH 2-1/16 5000 SWEEP ON LOWER SECTION OUTLET AND consent of vetcogray. UPPER SECTION OUTLETS DRAM an DATE C.RICE 15 APR 2009 REVERED at DALE X O IN APPROVED WO oAls: CUSTOMER 2 CONOCO PHIWPS/ARCTIC FOX/BELUGA PROJECT sASx9a+Ass APPRNa/1E x I mn¢r1 OF 1 • • • aiW I----24.69" ■ IMMO 25.63" I t EN gliiirnik = 1II1 "-"r,111 18.00" \ ,( 10.13" \ ■ 1.38", RIG MAT ',u.� - �'■ �.�1.0: 6.00° r_u- „- ,GROUN LEVEL TOP OF °, I lap- -110— ' b \ .8 I Lit i in i i 30.00° .i. �� _ r 1 49.50' 1 — niii it Alin / \ - wn 96.00° / I I i C20"CASING CUT—OFF I I I 6 I. l d '/ \a ;ill d \ I Qi / 20 CONDUCTOR \ 1 1 1I—_____-9-5/8"40#L80 CASING i i 4-1/2"L80 TUBING�,-- I --_��" 26#L80 CASING�_____.___ i PROPRIETARY NOTICE vetcog ray_ The information contained hereon is the confidential property of vetcogray and its affiliates. It is to be used only MB-230 MULTIBOWL SYSTEM for the benefit of vetcogray, and shall not be reproduced or used for ELEVATION VIEW OF 4-1/2" LANDING JOINT TO GROUND LEVEL any other purpose without written WITH 2-1/16 5000 SWEEP ON LOWER SECTION AND consent of vetcogray. UPPER SECTION OUTLETS DRAM PIE DM0 C.NICE 15 MR 2009 RENflOD 9W. WE X . rsowo�n er. w1s: CONOCO PHIWPS/ARCTIC FOX/BELUGA PROJECT 8 3 sEETi aNC REFEREKE X • i I II Ir I T'4.31 I4►rtil41II I'ilk ivkirim*fonii 91197" __ r �M\\ 50.12" — 1...,a4 ► C1� ,,,. 50.31' �►7:1:,--1111 4- .-5000 PSI ilia .- Y—MAS TREE .■n,., 71�� 12.30" k. 1111 IIa1 ••.. -- :;7.32. _ 141.: .18.0' J■rJ NC 'iI A IN •"ii 6.00' GROUND LEVEL/TOP OF•=_ 1p i .�.!.' 1 . ..I t 3 1 0.00' -' t 1I 49.50" '.6 II ' i ._i' I/ 1 /1950 I 96.00' I 20"CASING WT—OFF . �I I ' ' I 46.50" 11 I .�� p \11 L—_ 1 I i 20 CONDUCTOR y 1�9-5/8"40/L80 CASING / 3-1/2"9.2#L80 TUBING,, - —7"26#L80 CASING ` / \ II III PROPRIETARY NOTICE vetcog ray'. The information contained hereon is the confidential property of ray and N to be affiliates. It is to be used only MB-230 MULTIBOWL SYSTEM for the benefit of veteogray, WITH 4-1/2' TREE and shall not be reproduced or used for any other purpose without written WITH 2-1/16 5000 SWEEP ON LOWER SECTION AND consent of vetcogray. UPPER SECTION OUTLETS Dn.w Mt DAIS G RICE IS M*2009 IIE MO De WE x 76 rareoeo er. D.IE REFERQQ CONOCO PHILLIPS/ARCTIC FOX/BELUGA PROJECTNu S:—,.......6958;4 .....8a 4 I NC a� *aril re 1 • • g - s P i Utm IN W� 44� n � li I ,1 0 041 i O 6. K[z-1 1 1 I I g l�L g �5 S = 1 g: i o U. I �t 1 Pe it . I \ in I g it� �.,,,, I o$ m I § cl til 8 ■I \ 1 a ail. 1 \. j 3 t _\ — f .______1 : L.— d / H r `g` % R I Pi.8 4 I=' 1y ' �Y$ a 2 S :: ¢ ' I .N \ 3fX]3 UVd I JI ; Q . 30\ g JO\ •- 4 / n �\ r ,e C 11 pppB i i f � tlTt E • • ITEM DESCRIPTION 1 11" 5K SHAFFER SPHERICAL _. _ 2 11" 5K SHAFFER DOUBLE GATE 3 1 1" 5K DRILLING SPOOL W/ 3-1/8" 5K OUTLETS _ _ 4 2EA. 3-1/8" 5K HYDRAULIC VALVES 5 2EA. 3-1/8" 5K MANUAL VALVES 6 11" 5K SHAFFER SINGLE GATE 'MIL-3 EC ��1 =il_ __III ::-- T _ 01 2 7B"X 5"VBR's C: ■ ■ 3, �— 'J�11■1��L►�— Blind l.o '��I --, Rams i EN CIA:" . ■i J 1riINEI-- — •.,IP )1 11-0:4, — 4"DP __ 7 R ® � �` �� ( Q ' Ir Rams - — I z°a — I f 1 NI C i i { 3,108 Benga Project The information contained In this drawing is '_- ,„ 'I lho sole property of Doyon Drilling Inc.Any OYON 1ie reproduction in whole or part without the -... cu Arctic Fox j express written consent of Doyon Doyon ^r�i i L'N G ry Sub Section }}}7ttt Drilling Inc is prohibited. 4 r f` ' Shaffer 11-SA1 Slack 7 0' • Beluga River Unit 242-04 Area Index Map 7 1 0 BR 241 -3' RU 212-35 BRU 211-03: well sw d 1 U 212-35T and flowed while pulling out of hole from 4100' MD; killed , by building mud weight from 9.3 to 9.5 ppg. BR 43-34 ,BRU 224-ti4 illi - - I -3 0 BRU 232-g ,/e Proposed BRU 242-04 , BRU 244-C 4 1 7592 390383 i1e 0 BRU 212-09 .1 1 r- AOGCC March 26, 2012 • • Steve, I have made the corrections on page 3 as per our conversation. I have also included a copy of the MDT measurements from the offset well BRU 243-34 for back up evidence. Sorry about the confusion. Steve Shultz RECEVED MAR 2 8 2012 .Alaska Oil&Gas Cons. Commission Anchorage Well Name or Seismic Line TVD (SS) (Fracture G Pore Press Measurement Method BRU 243-34 —4090'from proposed well Sterling A 2957-3094 3.663-4.50:MDT flowing pressure, measured in July 2008 Sterling B 3175-3291 3.478-3.57;MDT flowing pressure, measured in July 2008 Sterling C 3326-3399 3.486-3.67 MDT flowing pressure, measured in July 2008 Beluga D 3479-3670 4.185-4.95 MDT flowing pressure, measured in July 2008 Beluga E 3740-4060 3.888-5.59.MDT flowing pressure, measured in July 2008 Beluga F 4224-4511 4.205-7.46'MDT flowing pressure, measured in July 2008 Beluga G 4,981 8.32 MDT flowing pressure, measured in July 2008 Beluga H 5005-5657 6.547-9.41 MDT flowing pressure, measured in July 2008 Beluga I 6,033 9.78 MDT flowing pressure, measured in July 2008 • • RECEIVED MAR 2 8 2012 Alaska Oil&Gas Cons.Commission Anchorage • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, March 27, 2012 12:24 PM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Cc: Schwartz, Guy L (DOA) Subject: FW: BRU 242-04 Questions Steve, I'm finishing my review of the BRU 242-04 Permit to Drill (PTD) application, but am having trouble with one final point. The Sterling A-C and Beluga D-J sands have been drilled in two nearby wells (BRU 211-03 and 243-34) using mud weights ranging from 9.2 to 9.8 ppg. (Note, however,the problem encountered in BRU 211-03 that is detailed in my separate email that is attached below.) The Mud Program Summary for BRU 242-04 indicates that CPAI plans to drill the Sterling A-C and Beluga D-J sands using mud weights ranging from 9.6 to 9.8+ ppg. But the Drilling Hazards Information section of the BRU 242-04 PTD application says that the anticipated reservoir pressure for the Beluga I sands is 3514 psi at 5969'TVD. This yields a gradient of 0.589 psi/ft, which is equivalent to a mud weight of about 11.35 ppg. Please help me reconcile this. Thanks, Steve Davies AOGCC From: Davies, Stephen F (DOA) Sent: Tuesday, March 27, 2012 11:50 AM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Cc: Schwartz, Guy L(DOA) Subject: RE: BRU 242-04 Questions Steve, Thanks for the information. I've been looking at records from wells located near the proposed BRU 242-04 well. Please be aware that nearby well BRU 211-03 was swabbed and apparently flowed (according to the mud log)while pulling out of the hole from 4100' MD. At that time,the weight of the mud in the BRU 211-03 wellbore was 9.2 to 9.3 ppg. Raising the mud weight to 9.5 ppg apparently solved the problem. According to the permit to drill application, CPAI plans to drill that same interval in BRU 211-03 with 9.6 ppg mud. Please be sure that all involved with drilling of BRU 242-04 are informed of the problem encountered in BRU 211-03. v Thanks again, Steve Davies AOGCC From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz @contractor.conocophillips.com] Sent: Tuesday, March 27, 2012 11:37 AM To: Davies, Stephen F (DOA) Subject: RE: BRU 242-04 Questions Sorry about that. • • From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Tuesday, March 27, 2012 8:09 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]RE: BRU 242-04 Questions Thanks Steve. Say,can you please provide a copy of the well logging program? Regards, Steve Davies AOGCC From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz @contractor.conocophillips.com] Sent: Friday, March 23, 2012 2:43 PM To: Davies, Stephen F (DOA) Subject: RE: BRU 242-04 Questions Steve, Good to hear from you. What we were basing the pore pressures off of was the offset well BRU 243-34 which is one location over from where we plan to drill BRU 242-04 (a little less then %2 mile). I have included the mud weights that we drilled BRU 242-04 which shows our heaviest mud at TD (7005'MD/6,781'TVD)was 9.6 ppg. This well is about 100 feet deeper TVD wise then the well we will be drilling. Take a look and see what you think. Thanks, Steve From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Thursday, March 22, 2012 6:58 PM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Schwartz, Guy L (DOA) Subject: [EXTERNAL]BRU 242-04 Questions Steve, Regarding the BRU 242-04 permit to drill application: The completion schematic diagram indicates that the expected pore pressure will range from 6.5 to 9.8 ppg, but under the Drilling Hazards Information section of the application,the text states that the production hole is expected to penetrate "near virgin reservoir pressure in the Beluga I sands," (which is closer to 10.5 ppg if my calculations are correct). Which pressures are correct, and will the proposed mud weights listed under the Mud Program Summary be sufficient? Could I get a copy of the proposed well logging program? Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 2 Steve's phone: 907-793-122 • AOGCC's receptionist: 907-793-1223 AOGCC's fax: 907-276-7542 AOGCC's website: http://doa.alaska.gov/ogc 3 Program Description Comments LWD-GR, Resistivity, Directional real-time Surface Hole LWD-GR, Resistivity, Density, Neutron real-time LWD-GR, ResinUvih/, Density, Neutron real-time LWD- Dipole Sonic, Directional, PWD dipole sonic in recorded mode (not real-time) Production Hole Mudlog -Mudgas, Chromatograph Mudlog-Cuthngs Description, dry samples 2 sets of washed and dried cuthngs samples every 10' MOT's drillpipe conveyed, 2 latch-ups Cased Hole Cement Bond Log To be run 24-48 hours after bumping the plug -- � _' ( ��c'�/ o~—� � / r / ' /Z • ,,, Drilling Mud Report $Wells BRU 243-34 LonocoPhillips Job: DRILLING ORIGINAL luid/Mud Checks Depth(TVD) Dens _ r PV OR YP OR Gel(10s) Gel(10m) FOtrale HTHP Fill 'Cu Chbr Llme _ Pf ,Ml - € _FART-- Stab:: Sand ..Cart. Date -Source Depth(5KB) (OKB) . „ ',,Type (Ib(9a}- Vs(sky) " (cp) OM/1005')(pN/1001P)(Ibt/100n')(ml/30m... (mLJ30m n) pH - (m0/L) (mg/L) =.(lb/Sbl) LGS(%) M9(m9/L) 0011,0) M OW Ratio (mlJmL) (mtimL) Pot(mg1L) (%) - (%) WelSore Suction Spud Mud 8.80 123 12.0 25.0 9.5 30 35.0 0.0 2.0 BRU 243-34 Suction 7,005.0 KlaStop/K... 9.80 63 25.0` 21.0 5.0 7.0 2.0 10.0 100 5.0 29,99... 9.0 BRU Polymer 243-34 ID /28/2008 Suction 79.9 79.9 Spud Mud 8.80 80 9.0 23.0 12.4 9.5 32 150 2.0 33.0 0/100 0.350 0.800 0.0 2.0 BRU 243-34 428/2008 Suction 79.9 79.9 Spud Mud 8.80 123 12.0 25.0 11.6 9.5 30 135 2.0 35.0 '0/100 0.400 0.800 0.0 2.0 BRU 243-34 /29/2008 Pit 0.0 Spud _8.80 76 27.0 27.0 9.0 23.0 0.0 9.6 32 150 0.0 0.000 11.6 0/100 0.800 0.000 0.0 2.0 BRU 243-34 429/2008 Pit 0.0 Spud 8.80 116 28.0 34.0 12.0 25.0 0.0 9.5 30 135 0.0 0.000 12.3 0/100 0.800 0.000 0.0 2.0 BRU 243-34 ./30/2008 Spud Mud - BRU 243-34 /30/2008 Pit 1 0.0 Spud 8.80 76 27.0 27.0 9.0 23.0 0.0 9.5 32 150 0.0 0.000 11.6 0/100 0.800 0.000 0.0 2.0 BRU 243-34 ./30/2008 Pit 1 0.0 Spud 8.80 116 28.0 34.0 12.0 25.0 0.0 9.5 30 135 0.0 0.000 12.3 0/100 0.800 0.000 0.0 2.0 BRU 243-34 431/2008 Pit 0.0 Spud 8.80 162 43.0 61.0 20.0 36.0 9.5 36 150 0.0 0.000 10.5 0/100 0.700 0.000 0.1 3.0 BRU 243-34 431/2008 Suction 200.0 200.0 Spud 9.10 201 50.0 80.0 29.0 37.0 9.4 40 200 5.8 0.000 10.5 0/100 0.550 0.000 3.0 BRU 243-34 „41/2008 Suction 1,254.0 1,241.7 Spud 9.10 193 32.0 57.0 17.0 41.0 8.7 48 200 0.0 0.000 7.9 0.600 0.000 0.3 ' BRU 243-34 41/2008 Suction 1,410.0 1,388.0 Spud 9.10 211 42.0 56.0 23.0 47.0 8.9 36 80 5.8 0.000 8.4 0.500 0.000 BRU 243-34 42/2008 Suction 2,990.0 2,791.9 Spud 9.65 227 32.0 44.0 12.0 28.0 8.4 32 150 6.0 0.000 7.9 0.550 0.000 0.8 BRU 243-34 • 42/2008 Suction 3,041.0 2,840.0 Spud 9.70 220 30.0 41.0 13.0 25.0 8.5 36 100 7.0 0.000 8.4 0.500 0.000 0.8 BRU 243-34 /3/2008 Suction 3,041.0 2,840.0 Spud 9.70 220- 30.0 41.0 12.0 25.0 8.5 36 100 7.0 0.000 8.4 0.500 0.000 0.8 BRU 243-34 45/2008 Pit 6 3,041.0 2,840.0 Empty pits 9.70 115 28.0 20.0 9.0 16.0 8.5 30 100 5.6 0.000 8.4 0.500 0.000 0.8 BRU 243-34 46/2008 Pit 6 3,041.0 2,840.0 Empty pits ' 9.70 115 28.0 20.0 9.0 16.0 8.5 30- 100 5.6 0.000 8.4 0.500 0.000 0.8 BRU 243-34 47/2008 Pit 3 3,041.0 2,840.0 KlaStop/K... 9.20 72 17.0 21.0 6.0 7.0 0.0 9.9 80 33,000 1.2 0.000 0.0 0/100 5.200 29,99... 0.0 5.0 BRU Polymer 243-34 ./7/2008 Pit 3 3,041.0 2,840.0 KlaStop/K... 9.20 72 17.0 21.0 6.0 7.0 0.0 9.9 80 33,000 1.2- 0.000 0.0 0/100 5.200 29,99... 0.0 5.0 BRU Polymer 243-34 Page 1/4 • e CSC 1 3_ 7_3 ,, (2 &Wl Mud Report gt- BRU 243-34 ConocoPhdGps Job: DRILLING ORIGINAL luld/Mud Checks Depth(ND) -$ - Dens PV OR. VP OR Gel(10s) Gel(10m) Filtrate' 11TNP Fit` Ca -Plot , Lime MBT. Stab , -_ Pr -MI Sand -Con '; i -.Date Source Depth(WO Y (5KB) Type '4Ib/9al) Vls(sIW) .(cp) (Ib01001P)(MOW)(Ib01001P)(mU30,0- (mL13Qnin)- -PH (m gIL) -01910 (Inibbl) LOS(C) Mg(O14IL) 4b/bbl) IV) OW Ratio (mUmL), (mLSoL) Pol(mg/L) (C) (%) Wellbore 1/9/2008 Suction 5,083.0 4,859.1 KlaStop/K... 9.30 65 20.0 25.0 6.0 7.0 2.2 10.0 80 35,000 2.2 0.000 0.9 0/100 6.200 34,00... 0.1 6.0 BRU Polymer 243-34 49/2008 Suction " 5,464.0 5,240.0 KlaStop/K... 9.30 66 23.0 24.0 6.0 7.0 2.0 9.9 100 33,000 1.2 0.000 0.9 0/100 6.000 34,00... 5.5 BRU • Polymer 243-34 3/10/2008 Suction 6,411.0 6,187.0 KlaStop/K... 9.60 62 24.0 23.0 7.0 9.0 1.8 9.9 100 32,000 2.1 0.000 1.6 01100 6.200 32,00... 7.0 BRU Polymer 243-34 410/2008 Suction 6,590.0 6,366.0 KlaStop/K... 9.50 63 26.0 25.0 8.0 10.0 1.8 10.0 100 34,000 4.1 0.000 1.9 0.5/99.5 6.800 32,00... 8.0 BRU Polymer 243-34 1/11/2008 Suction 6,907.0 6,682.9 KlaStop/K... 9.60 62 25.0 26.0 7.0 9.0 1.6 9.8 100 30,000' 0.0 0.000' 6.0 1.1/98.9 6.400 0.000 8.0 BRU Polymer 243-34 411/2008 Suction 6,907.0 6,682.9 KlaStop/K... 9.60 62 25.0 26.0 7.0 9.0 1.6 9.8 100 30,000 0.0 0.000 2.1 1.1/98.9 6.400 0.000 8.0 BRU Polymer 243-34 411/2008 Suction 7,005.0 4 771'KlaStop/K... 9.60 57 23.0 23.0 7.0 9.0 1.6 9.8 100 29,000 4.1 0.000 2.1 1.1/98.9 6.400 32,00... 8.0 BRU / Polymer 243-34 411/2008 Suction 7,005.0 KlaStop/K... 9.60 57 23.0 23.0 7.0 9.0 - 1.6 9.8 100 29,000 4.1 0.000 6.0 1.1/98.9 6.400 32,00... 8.0 BRU Polymer 243-34 412/2008 Suction 7,005.0 KlaStop/K... 9.80 62 26.0 28.0 7.0 11.0 1.8 10.1 100 30,000 0.0 0.000 2.1 1.1/98.9 6.600 0.000 9.0 BRU Polymer 243-34 412/2008 Suction ' 7,005.0 KlaStop/K... 9.80 64 26.0 27.0 7.0 11.0 1.8 10.1' 100 30,000 4.7 0.000 2.1 1.1/98.9 6.600 29,99... 9.0 BRU Polymer 243-34 413/2008 Suction 7,005.0 KlaStop/K... 9.80 65 26.0 26.0 7.0 11.0 1.8 10.0 100 29,000 4.7 0.000 2.1 1.1/98.9 6.800 29,99... 9.0 BRU Polymer 243-34 413/2008 Suction 7,005.0 KlaStop/K... 9.80 64 26.0 25.0 6.0 10.0 1.8 10.0 100 29,000 4.7 0.000 2.1 1.1/98.9 6.800 29,99... 9.0 BRU Polymer 243-34 414/2008 Suction 7,005.0 KlaStop/K... 9.80 64 26.0 26.0 6.0 10.0 1.8 10.0 100 29,000 4.7 0.000 2.1 1.1/98.9 6.800 29,99... 9.0 BRU Polymer 243 34 414/2008 Suction 7,005.0 KlaStop/K... 9.80 62 26.0 27.0 7.0 11.0 1.8 9.9 100 30,000 4.7 0.000 1.8 1.1/98.9 6.800 29,99... 9.0 BRU Polymer 243-34 • 415/2008 Suction ' 7,005.0 KlaStop/K...- 9.80 84 22.0 22.0 5.0 7.0 2.0 10.1 '80 28,000 3.0 0.000 1.8 1.1/98.9 6.900 24,00... 8.0 BRU Polymer 243-34 415/2008 Suction 7,005.0 KlaStop/K... 9.80 63 25.0 21.0 7.0 9.0 . 2.0 10.0 100 30,000 4.7 0.000 5.0 1.1/98.9 6.900 29,99... 9.0 BRU Polymer 243-34 416/2008 Suction 7,005.0 KlaStop/K... 9.60 69 20.0 25.0 4.0 6.0 2.2 10.1 80 27,000 4.3 0.000 2.5 1.1/98.9 6.900 29,99... 8.0 BRU Polymer 243-34 416/2008 Pits 7,005.0 KlaStop/K... 9.60 68 22.0 22.0 5.0 7.0 2.0 10.0 80 28,000 4.2 0.000 2.1 1.1/98.9 6.900 31,00... 8.0 BRU Polymer 243-34 117/2008 Suction 7,005.0 KlaStop/K... 9.60 69 21.0 23.0 5.0 7.0 2.0 10.0 80 28,000 4.2 0.000 2.1 1.1/98.9 6.900 31,00... 8.0 BRU Polymer 243-34 417/2008 Pits 7,005.0 KlaStop/K... 9.60 65 21.0 24.0 5.0 7.0 2.0 10.0 120 29,000 4.2 0.000 1.8 1.1/98.9 6.800 31,00... 8.0 BRU Polymer 243-34 Page 2/4 ,:, Drilling Mud Report Wells BRU 243-34 L.onocoYhil lips Job: DRILLING ORIGINAL Auld/Mud Checks Ms - Depth(TVD) .. Dens PV OR VP OR Gel(10s) Gel(10m) Filtrate_ HTHP Fill'.. =Ca.. Cher Lime MBT Stab Pt Mf Sara Com Date Source Depth(SK8) (an) ''Type (Ibis I) Vis(s/g) (ct) (IbfHO01P)(16V100fP)(Ibfl100h')(mL(30at_.. (mU3Omin) pH (mglL) (mgfL) (Wbbl) LOS(%) Mg(mg!L) (Iblbbl) (V) OW Ratio (mt/mL) (CUmL) Pot(agIL) (%) _(`) Weitbore ;/18/2008 Suction 7,005.0 KlaStop/K... 9.60 64 21.0 22.0 5.0 7.0 2.0 9.9 180 28,000 4.2 0.000 1.8 1.1/98.9 6.700 31,00... 8.0 BRU Polymer 243-34 ;/18/2008 Suction 7,005.0 KlaStop/K... 9.60 64 21.0 22.0 5.0 7.0 2.0 9.9 180 28,000 4.2 0.000 1.8 1.1/98.9 6.700 31.00... 8.0 BRU Polymer 243-34 • 418/2008 Suction 7,005.0' KlaStop/K... 9.60 61 21.0 19.0 4.0 6.0 2.2 10.0 140 27,000 4.3 0.000 1.8 1.1/98.9 6.700 29,99... 8.0 BRU Polymer 243-34 418/2008 Suction 7,005.0 KlaStop/K... 9.60 61 21.0 19.0 4.0 6.0 - 2.2 10.0 140 27,000 4.3 0.000 1.8 1.1/98.9 6.700 29,99... 8.0 BRU Polymer 243-34 ,/25/2008 6,039.0 5,815.0 Completion 8.64 BRU Fluid 243-34 426/2008 In 6,039.0 5,815.0 KCL Brine 9.60 28 BRU 243-34 ./27/2008 6,039.0 5,815.0 KCL Brine 9.50 28 8.3 BRU 243-34 428/2008 Suction 6,039.0 5,815.0 KCL Brine 9.50 28 8.3 BRU 243-34 429/2008 Suction 6,039.0 5,815.0 Completion 9.75 30 BRU Fluid 243-34 ;/30/2008 Suction 6,039.0 5,815.0 Completion 10.30 29 BRU Fluid 243-34 '/1/2008 Suction 6,000.0 5,776.0 Completion 8.60 26 8.3 BRU Fluid 243-34 - - '/2/2008 Suction 5,147.0 4,923.1 Completion 8.60 26 8.3 BRU Fluid 243-34 '/3/2008 Suction 5,539.0 5,315.0 Completion 8.60 26 8.3 BRU Fluid 243-34 '/4/2008 Suction 5,539.0 5,315.0 Completion 10.20 28 9.0 BRU Fluid 243-34 • '/5/2008 Suction Completion 10.00 30 9.0 BRU Fluid 243-34 /6/2008 Suction 6,547.0 6,323.0 Completion 10.00 28 8.2 BRU Fluid 243-34 '/7/2008 Suction 6,994.0 6,769.9 Completion 10.20 30 8.3 BRU Fluid 243-34 '/8/2008 Suction 6,994.0 6,769.9 Completion 10.20 30 8.3 BRU Fluid 243-34 '/9/2008 6,994.0 6,769.9 Completion 26 BRU fluids 243-34 713/2008 Suction 7,000.0 6,775.9 Completion 10.30 26 BRU Fluid 243-34 Page 3/4 • ,:, Drilling Mud Report 6 &Wells BRU 243-34 ConocoPh llips Job: DRILLING ORIGINAL luid/Mud Checks - API:. Elec = - SofMs, Depth(ND) Dens PV OR YP OR Gel(10s) Gel(10m) Filtrate HTHP Flit Ca Chloe Lime MBT Stab _ Pf Mt -' F. Sand -'C�• :: Date '—`t 'Source Depth(MB) (nKB) Type _ (Poy7at)' Vls(slgl) (cp) (Wf/100H')(Ibfl100fi9(I)tI100fP)(mUl30m... (m M) pH (m9il.) (m9IL) (lbfnbl)'., LOS(%) Mg(m9ILi. (IbIbbI) (NI- ,OW Ralto WO-) (m1/m1-) Pot(mgn-) (%) (%6) Wellbwe '/16/2008 Suction 6,994.0 6,769.9 Completion 26 8.7 29,500 BRU Fluid 243-34 '/17/2008 Suction 6,994.0 6,769.9 Completion 8.60 8.9 29,500 BRU • Fluid 243-34 '/18/2008 Suction 6,994.0 6,769.9 Completion 8.60 8.8 29,500 BRU Fluid 243-34 — - '/20/2008 Suction BRU 243-34 /21/2008 Suction 5,129.0 4,905.1 Completion 8.63 26 8.7 19,500 BRU Fluid 243-34 '/22/2008 Suction 5,129.0 4,905.1 Completion 8.63 8.6 19,000 BRU Fluid 243-34 '/23/2008 Flowline Completion 8.60 28 BRU Fluid 243-34 724/2008 Flowline Completion 8.60 28 8.5 BRU Fluid 243-34 725/2008 Flowline Completion 8.60 29 ' 8.5 BRU Fluid 243-34 '/26/2008 Flowline Completion 8.60 28 8.5 BRU Fluid 243-34 727/2008 Flowline Completion 8.60 BRU Fluid 243-34 ill Page 4/4 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 04, 2012 3:03 PM To: 'Shultz, Steve(Orbis Engineering, Inc.)' Cc: Davies, Stephen F (DOA) Subject: BRU 242-04 ( PTD 212-041) Steve, I am reviewing the PTD for BRU 242-04 .... Please supply the following information: 1)Wellhead sketch and specs. 2) production tree sketch and SVS system summary. (surface and SSSV) 3) map view of Diverter layout on pad. Rig set up etc. 4) Initial BOP configuration in step#6 ... ie ram pipe size from top to bottom. Comments: -Testing casing to 4500 psi so BOP will be same. -Sundry approval for frac stimulation. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/4/2012 t • 'e i, Casing Design Performance Properties for BRU 242-04 Size Hole Weight Grade Conn. Internal Condition Collapse Tensile Strength Yield Joint Body 20" NA 154.19 X65 Welded Conductor New ppf 9-5/8" 12.25 40 ppf L-80 BTC 5750 psi New 3090 947 M 916 M 7" 8.75 26 ppf L-80 BTC-M 7240 psi New 5410 641 M 604 M Casing Setting Depth Rational: 20" @ 108' MD RKB Conductor casing driven to provide sufficient anchor for diverter system. 9-5/8" @ 3374' MD RKB Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling 8-3/4" hole to top of reservoir. 7" @ 7248' MD RKB Production casing is near the bottom of the Beluga sands to provide pressure integrity and zonal isolation. Assumptions a) Use of lightweight cement slurries cement slurries for design purposes b) Temperature deration of pipe properties has not been applied to all strings c) Assume higher than expected mud weight, -conservative for most cases Proposed casing scheme Casing depths, mud weights&TOC: OD (in) Name Type Measured Depths RKB (ft) Mud at Shoe RKB=18.5' (ppg) Hanger Shoe TOC 20" Conductor Casing 18.5 108 20 N/A 9 5/8" Surface Casing 17.5 3374 20 10.0 7" Production Casing 16.5 7248 3147 10.3 Design Factors The design factors used for all casing strings, pipe body and connections are as follows: Burst 1.15 Collapse 1.05 Axial - Tension 1.4 - Compression 1.4 Triaxial 1.31 20" Conductor-Design N/A, driven to refusal at 110' RKB prior to spud 9 5/8" Surface Casing Load Cases Critical load cases in blue Burst Load Cases Load Case External Pressure Internal Pressure Temperature Profile Profile Profile Displacement to gas Pore pressure Well displaced to gas. Kick circulation temperature Pressure test Pore pressure 3000 psi surface Geothermal gradient pressure + 9.8 ppg fluid column Collapse Load Cases Load Case External Pressure Internal Pressure Temperature Profile Profile Profile Full/Partial Mud weight casing Evacuated to shoe Geothermal gradient Evacuation was run in (9.0 ppg) Cementing 12 ppg slurry to Displacement fluid Geothermal gradient surface (9.8 ppg) Axial Load Cases Load Case Load Criteria Running in hole 3.0 ft/s Overpull force 100 000 lbs Service loads cementing Results Safety Factors: Depth (MD) OD/Weight/Grade Connection Minimum Safety Factor(Abs) (ft) Burst Collapse Axial Triaxial 3374 9 5/8", 40#, L-80 BTU') 1.85 B5 2.48 C6 3.47 A4 2.14 B5 (1) BTC connection axial strength corrected for minimum yield strength A4 Overpull force C Connection Critical B5 Pressure Test C2 Cementing C1 Full/Partial Evacuation No buckling as string is cemented to surface. 7" Production Casing Load Cases Critical load cases in blue italics • 0 Burst Load Cases Load Case External Pressure Internal Pressure Temperature Profile Profile Profile Pressure test Pore pressure at 4750 psi + 8.6 ppg Geothermal gradient Beluga and Sterling brine Surface tubing leak 8.6 ppg with pore SITP+ Completion Geothermal gradient pressure up to fluid column (8.6 ppg) 2358psi Normal production 9.6 ppg with pore 1500 psi IA pressure Flowing temperature pressure + 8.6 ppg fluid column Stimulation Surface 9.8 ppg with pore 4750 psi treating Fluid temperature- leak pressure pressure 8.6 ppg fluid 45F Bullhead 9.6 ppg with pore 2500 psi + 8.6 ppg Bullhead fluid pressure fluid column temperature-45°F Collapse Load Cases Load Case External Pressure Internal Pressure Temperature Profile Profile Profile Full Evacuation 9.8 ppg above TOC Fully evacuated Geothermal gradient Axial Load Cases Load Case Load Criteria Running in hole 3.0 ft/s Overpull force 100 000 lbs Service loads Bullhead Results Safety Factors Depth MD(ft) OD/WeightlGrade Connection Minimum Safety Factor(Abs) Burst Collapse Axial Triaxial BTC- 16.5 7", 26 ppf, L-80 DeRated 1.45 B7 10.72 C7 2.44 A4 1.81 B7 1000 1.47 B7 8.79 C7 2.25 A4 1.80 B7 3374 1.51 B7 3.67 C5 2.69 B8 1.83 B7 3946 1.50 B5 3.15 C5 2.92 A4 1.87 B7 5913 1.45 B5 2.12 C6 3.47 B8 1.81 B5 7248 1.42 B5 1.73 C6 3.48 B8 1.75 B5 B5 Pressure Test B7 Stimulation Surface Leak B8 Injection Casing C5 Full Evacuation Production A4 Overpull Force C7 Gas Migration (Collapse) C6 Above/Below Packer No buckling Page 1 of 2 • Schwartz, Guy L (DOA) From: Shultz, Steve(Orbis Engineering, Inc.) [Steve.Shultz @contractor.conocophillips.com] Sent: Monday, April 09, 2012 4:27 PM To: Schwartz, Guy L(DOA) Subject: RE: BRU 242-04 ( PTD 212-041) Attachments: 2012040919255855.pdf Guy, I was able to look at an offset well BRU 243-34 which was drilled in 2008 and is one location away which I have attached. As you can see they drilled the well with no indication of drill gas in the mud and during periods of circulating no gas was evident at surface. I have included the morning reports with the mud program. The two wells 211-03 and 224-34 were drilling by Chevron in 85 and I couldn't find any mud logs. In fact I doubt if they ran any mud logs on surface which isn't the norm out at Beluga. Thanks, Steve From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @ alaska.gov] Sent: Thursday, April 05, 2012 3:39 PM To: Shultz, Steve(Orbis Engineering, Inc.) Subject: [EXTERNAL]RE: BRU 242-04 ( PTD 212-041) Steve, Just noticed the B,C ,T calc for the casing are in the PTD packet either. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz @contractor.conocophillips.com] Sent: Thursday, April 05, 2012 2:42 PM To: Schwartz, Guy L(DOA) Subject: RE: BRU 242-04 ( PTD 212-041) Guy, Let me know if you need anything else. Thanks, Steve From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, April 04, 2012 3:03 PM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Davies, Stephen F (DOA) Subject: [EXTERNAL]BRU 242-04 ( PTD 212-041) Steve, 4/9/2012 Page 2 of 2 I am reviewing the PTD for BRU 242-04 .... Please supply the following information: 9 pP Y 1)Wellhead sketch and specs. 2) production tree sketch and SVS system summary. (surface and SSSV) 3) map view of Diverter layout on pad. Rig set up etc. 4) Initial BOP configuration in step#6 ... ie ram pipe size from top to bottom. Comments: -Testing casing to 4500 psi so BOP will be same. -Sundry approval for frac stimulation. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/9/2012 0. co t t oa co CO Oa CO a' Y 8 0 0 o m m 40 0 0 0 0 0 0 0 o r3 r3 r3 nl g v g 8g m;, ° c 0 0 0 0 o c 0 0 0 0 0 O0 0 0 0 0 a n 11111111I11P111 — —' A 'u 1111111111111111111114. rrrrrrrrrrrrrur O 0Errai 1 IMEINTIFTEMEIMIER $p ,,,,,,,,,,,,,,,,1 !„�1 11 iHIUIIIIIHIPflU!Ii 111111111111111r, ingiNEEMENEMV 11111111111111111i N W N W NA W N W N W N W N W N W N W N W N W N W N W N W N W N W N W N W N W N W AW WA Wz etm 4A/„ 1,,W Wx W W AW W,3 WA AA W W WA AA wm W W WA tAit'm W W Y'c (tc WWe �c �c We we we �c we we wecccccc Ac As,+ y' z W A A A A A A A A A A q,' D r a TRANSMITTAL LETTER CHECKLIST WELL NAME - PTD# 2_-- C L1 I °`Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: L-L L L POOL: t r. t irr-cam (1(-11-“-- 1/1-/-k/ 9 7 Check Box for 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 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:9/09/2011 410 0 00 co 0) o a) a , NN N � @ , , , � � N . C NNN' 2 a0 ca f>i .0 , < < <, , , . . . '0 '0 q , 0 O V. V. V. N; ; N. E 0 x x > N, Cl)' io' 0, ? .to Cn N C C C w I �� O o 0) c) mG °' 3' 3; . o; w; cu ate)' 0' �� E, O' �� E' a n L L L o �; �; a. �' v' m w' a �. ao' 0 Cc) C 0) O) Ca �, �. �, �, . fa' �, o', 0) a �. . O. L � U cv U �, E o w' S. I-i Q' N' 0 '0, Z �� W W W q c �� 0 y, �, co 0 o �. CO ' '3' ' Z ' a' ' c O . 2 > . . w' d' 0, d,' o cry ° , ° p N c 0 Z' w' w. w' �. 0' 0 � m' ' OS 0 0)OC w Z. Z. Z' >' UA 0 3 O a p) N' m' C 0 CO N ' �' Z. p. 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' 5. \• 0 O 0) V' t, c. a -pa 2' co T N a, a. 0' 3' '0' ' o' o' >. c N' 0,, 07 O: -c—: w' p O U, 0' C, o, '0 IL ay L' •p. •0. -o. p' C, 0. A' -0' ' aT co ••N. a a Q>. .N ,-, L. 3. 0. o' y; c o. 0' co c�' N c c'U �, 0 E' �' a). m. .o' , °)i '3' 0 " CO ca' @' v 0' 7 -0 N aS' O' U, m 0 CO V' CO c, O' c' c' c. z c, �, c, � 0 o o ac), is o; o; y', . o' N; o; cs. as' o; o; •3. v. 3' . oy vi a �. '3; N, �. v a 0. �. �.CD c• 8 a)' 0. — U' .5 N Is a N. a -o. 0' c' O' y' o. 0' c' w W' ,, �' L. E' .a' .• o a`,, a), .0 °) 0 a) ' °' o 0 a`). a)' C �. 3' Ch; o. C 2. �. 2' c. v, as v. 0 0, r, °' N a' 5'' a>as m a), co. p`0 c z; a, . n . �. � co ,0,, 0,, amt.) ¢', a, 0,, cnU, 0' 0, 0 <, �. Q, 0, m m, 0 ,, —, �, a 0', U), U, 0, 0 �. 0. P O — N M V t0 CO CO 0) 0 N CO eY t0 CO N- a) 0) 0 N CO LO CO N- CO O) o — � N M cr If) CO )� a0 0) — '— CV N N N N N N N N N CO CO CO M aM CO CO CO CO CO 0 N N N N a) a; � c CD O c co�O O l�6 N (U N U O O Q N O Q ,n CO N o p V c M U N 0 al N w '� E/,y.�.. 'c a 0 c . m o a 0 0 0 o I E Q U) to $ 0 Q cq a • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-bun urillir services LIS Scan Uti_ _cy 2-k% c� $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 17 07:35:33 2012 Reel Header Service name LISTPE Date 12/07/17 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN • Comments STS LIS Writing Library. Scientific Technical Services • Tape Header Service name LISTPE Date 12/07/17 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services i Physical EOF Comment Record TAPE HEADER Beluga River Unit MWD/MAD LOGS # WELL NAME: BRU 242-04 API NUMBER: 502832016400 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 17-JUL-12 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: -XX-0009498073 -XX-0009498073 LOGGING ENGINEER: LUCAS SMITH BENJAMIN SCH OPERATOR WITNESS: DONNIE LUTRI DONNIE LUTRI SURFACE LOCATION SECTION: 4 TOWNSHIP: 12N RANGE: lOW FNL: 201 FSL: FEL: 368 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 110.64 GROUND LEVEL: 92.14 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 110.0 2ND STRING 8.750 9.625 3335.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) , UNLESS OTHERWISE NOTED. 2. ALL VERTICA. DEPTHS ARE TRUE VERTICAL DEPTH--JBSEA (TVDSS) , PER REQUEST FROM RICK LEVINSON (CPAI) . 3. MWD RUNS 100 & 200 WERE DRILLED TO CLEAN-OUT THE CONDUCTOR AND TO CREATE ACCOMODATION SPACE FOR THE MWD TOOLS. NO MWD TOOLS WERE INCLUDED IN THE BHA - NO DATA ARE PRESENTED. 4. MWD RUNS 300 & 400 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PRESSURE WHILE DRILLING (PWD) , DRILLSTRING DYNAMICS SENSOR (DDSr) , AND THE EM-P4M TELEMETRY SYSTEM. MWD RUN 400 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AZIMUTHAL LITHO-DENSITY (ALD) , AND BI-MODAL ACOUSTIC TOOL (BAT) . 5. MERGED DIGITAL AND LOG DATA WERE SHIFTED TO A CBL/GR LOG RUN IN BRU 242-04 ON 30 JUNE 2012. INSTRUCTIONS WERE CONVEYED VIA A PHONE CONVERSATION (2 JULY 2012) BETWEEN RICK LEVINSON (CPAI) AND BUSTER BRYANT (SD) . ANNOTATIONS AND LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTHS. 6. NOTE: WAVEFORMS ARE NOT SHIFTED. 7. MWD RUNS 100-400 REPRESENT WELL BRU 242-04 WITH API #50-283- ' 20164-00. THIS WELL REACHED A TOTAL DEPTH OF 7221'MD/6649'TVD/ 6539'TVDss. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION DGRC DGR COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDL/ALCDLC ALD LCRB COMPENSATED DENSITY ADCL/ALDCLC ALD LCRB DENSITY CORRECTION APEL/ALPELC ALD LCRB Pe FACTOR ALRP/ALRPM ALD RPM (SLIDE INDICATOR) AHSI/ALHSI ALD HOLE SIZE INDICATOR BTCS BAT COMPRESSIONAL SLOWNESS BCSS/BTCSS BAT COMBINED SHEAR SLOWNESS BVPS/BTVPVS BAT VP/VS RATIO BSFG/BTSFLAG BAT SHEAR FLAG PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED, 8.75" BIT MUD WEIGHT: 9.45 - 9.65 PPG WHOLE MUD CHLORIDES: 32,000-38,000 PPM FORMATION WATER SALINITY: 3000 - 5000 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 65 G/CC LITHOLOGY: SANDL JNE TEMPERATURE: DYNAMIC FROM EWR-P4, 118.8°F @ TD ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/07/17 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 169.0 7171.0 FET 178.5 7163.5 RPX 178.5 7163.5 RPS 178.5 7163.5 RPM 178.5 7163.5 RPD 178.5 7163.5 ROP 218.5 7218.5 DTSH 3217.0 7073.0 DTC 3217.0 7073.0 SCRA 3217.0 7073.0 RHOB 3331.0 7128.5 NPHI 3331.0 7115.0 PEF 3331.0 7128.5 FCNT 3331.0 7115.0 DRHO 3331.0 7128.5 NCNT 3331.0 7115.0 CALN 3353.0 7128.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 3132.5 3130.5 3301.5 3297.5 3313.0 3307.0 3339.0 3333.0 3366.0 3361.5 3396.0 3392.0 3405.0 3399.5 3407.5 3403.5 3436.0 3431.5 3448.0 3443.5 3455.5 3451.0 3497.0 3493.0 3504.0 3500.5 3509.5 3506.0 3526.5 3522.0 3542.5 3538.5 3558.0 3554.5 3591.5 3588.0 3607.5 3603.5 mow 3636.0 3632.` 3652.5 3649.5 3661.0 3658.5 3677.5 3674.5 3752.5 3749.5 3820.5 3818.0 3852.0 3847.5 3855.0 3850.0 3880.0 3875.5 3896.0 3890.5 3904.5 3900.0 3909.5 3905.0 3947.0 3942.5 3971.0 3966.5 4002.5 3998.5 4037.5 4034.5 4083.0 4077.5 4113.0 4108.0 4121.0 4115.0 4136.0 4129.5 4171.5 4166.5 4201.5 4196.0 4206.0 4200.5 4226.5 4221.0 4251.5 4246.5 4272.5 4267.5 4288.5 4283.0 4307.5 4302.0 4315.0 4311.0 4332.5 4328.0 4338.0 4333.0 4341.0 4336.5 4367.0 4362.5 4434.0 4428.5 4445.5 4441.5 4452.0 4449.0 4548.0 4544.0 4553.5 4551.0 4560.5 4556.5 4587.5 4585.0 4602.0 4598.5 4605.0 4601.5 4614.0 4610.5 4624.5 4621.5 4653.5 4651.5 4677.5 4675.0 4682.0 4679.0 4694.0 4690.0 4739.0 4736.0 4754.5 4750.0 4806.0 4803.0 4809.0 4806.5 4813.5 4811.0 4818.5 4816.0 4841.0 4837.5 4855.'0 4851.0 4870.5 4866.5 4876.0 4872.0 4880.5 4877.0 4932.0 4929.0 4965.0 4962.0 5014.5 5010.5 5017.5 5013.0 5020.5 5017.5 5025.0 5021.5 5042.5 5040.5 5050.0 5049.5 5073.5 5071.5 5090.0 5088.0 5102.5 5100.0 5180.0 5176.0 5203.0 5199.0 5206.0 5202.0 5295.5 5291.0 5302.5 5299.5 5307.5 5303.5 5318.5 5314.0 5375.0 5371.0 5387.5 5385.0 5404.0 5403.0 5458.0 5456.0 • 5471.0 5466.5 5478.0 5474.0 5480.0 5476.0 5485.0 5480.0 5512.0 5510.0 5521.5 5520.5 5524.0 5522.0 5530.5 5529.5 5543.5 5542.5 5547.0 5546.0 5559.0 5556.0 5575.5 5574.0 5585.0 5583.0 5609.5 5607.5 5618.5 5617.5 5626.5 5626.0 5630.5 5630.5 5653.0 5651.5 5655.0 5653.5 5673.5 5673.0 5690.0 5690.0 5693.0 5692.5 5696.5 5695.5 5700.5 5698.0 5717.5 5716.5 5737.0 5735.5 5748.0 5746.5 5752.0 5750.5 5771.5 5770.5 5809.5 5809.0 5818.0 5816.5 5826.0 5825.0 5831.5 5831.0 5852.0 5850.0 5857.0 5854.5 5874.5 5872.0 5892.5 5890.0 5899.0 5897.5 5905.0 5903.0 5914.5 5912.0 5955.5 5954.5 5961.5 5960.0 5966.0 5964.0 5977.0 5976.0 6016.5 6016.5 6022.5 6023.0 6040.0 6040.5 6043.5 6044.0 6058.0 6058.5 6066.0 6066.5 6072.0 6072.0 6101.5 6100.0 6108.5 6107.5 6116.0 6114.5 6119.5 6119.0 6133.0 6132.0 6146.0 6146.0 6158.0 6158.5 6164.0 6164.5 6177.5 6177.0 6180.5 6179.0 6196.5 6195.E 6206.0 6206.0 6240.0 6239.5 6274.5 6273.0 6284.5 6283.0 6311.0 6309.5 6327.0 6325.5 6333.0 6331.0 6359.5 6359.5 6370.5 6368.5 • 6397.5 6395.5 6409.0 6409.0 6414.5 6414.0 6417.0 6416.5 6428.0 6427.5 6459.0 6459.0 6463.0 6463.Q 6473.0 6473.0 6477.5 6478.5 6481.0 6480.0 6488.0 6487.0 6498.0 6496.5 6517.5 6517.0 6522.5 6522.0 6528.5 6529.0 6536.5 6536.0 6542.0 6541.5 6547.0 6548.5 6560.0 6559.5 6567.0 6566.5 6590.5 6590.0 6627.5 6628.0 6681.5 6684.0 6683.5 6685.5 6692.0 6694.0 6704.0 6707.0 6708.5 6711.0 6711.5 6714.0 6713.5 6716.0 6721.5 6722.5 6723.5 6726.0 6726.0 6728.5 6732.5 6735.5 6742.5 6746.5 6754.5 6758.0 6756.5 6760.0 6793.0 6797.5 6803.0 6807.0 6817.5 6821.5 6827.0 6829.5 6830.5 6832.5 6840.5 6843.0 6842.5 6845.0 6859.0 6861.0 6869.5 6871.0 6880.5 6883.5 6889.0 6892.5 6894.0 6897.5 6900.0 6903.5 6902.0 6906.5 6913.5 6917.5 6916.5 6920.0 6923.0 6928.5 6941.0 6944.0 6942.5 6945.5 6970.0 6971.0 6972.0 6973.0 6981.0 6982.5 6984.0 6985.5 6986.5 6988.5 6996.5 6998.0 7002.5 7003.5 7008.5 7009.0 7034.5 7037.0 7041.5 7044.5 7045.5 7047.5 7048.5 7051.0 7063.5 7065.5 7075.5 7078.5 7079.0 7081.5 $ . # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 167.0 3346.0 MWD 4 3346.0 7221.0 $ REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 ' CALN MWD IN 4 1 68 12 4 ' PEF MWD B/E 4 1 68 16 5 DTC MWD USPF 4 1 68 20 6 SCRA.MWD NONE 4 1 68 24 7 , GR MWD API 4 1 68 28 8 DTSH MWD USPF 4 1 68 32 9 FET MWD HR 4 1 68 36 10 RPX MWD OHMM 4 1 68 40 11 RPS MWD OHMM 4 1 68 44 12 RPM MWD OHMM 4 1 68 48 13 RPD MWD OHMM 4 1 68 52 14 ROP MWD FPH 4 1 68 56 15 FCNT MWD CP30 4 1 68 60 16 NCNT MWD CP30 4 1 68 64 17 NPHI MWD PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 169 7218.5 3693.75 14100 169 7218.5 RHOB MWD G/CC 0.762 2.961 2.24658 7596 3331 7128.5 DRHO MWD G/CC -4.368 0.274 0.0491586 7596 3331 7128.5 CALN MWD IN 8.34 13.47 8.91182 7071 3353 7128.5 PEF MWD B/E 0.39 13.25 2.76353 7596 3331 7128.5 DTC MWD USPF 84.3511 172.626 121.971 7713 3217 7073 SCRA MWD NONE 1.4906 2.7313 2.01214 7692 3217 7073 GR MWD API 16 119.6 66.2901 14005 169 7171 DTSH MWD USPF 161.54 338.93 244.938 7692 3217 7073 FET MWD HR 0.09 156.49 1.78612 13932 178.5 7163.5 RPX MWD OHMM 0.15 1111.44 29.418 13932 178.5 7163.5 RPS MWD OHMM 0.2 1281.53 48.0128 13932 178.5 7163.5 RPM MWD OHMM 0.28 1669.2 55.9944 13932 178.5 7163.5 RPD MWD OHMM 4.54 2000 96.2062 13932 178.5 7163.5 ROP MWD FPH 0.24 9515.36 141.687 14001 218.5 7218.5 FCNT MWD CP30 389.22 2018.05 825.842 7569 3331 7115 NCNT MWD CP30 92760.3 153715 117286 7569 3331 7115 NPHI MWD PU 15. 61 105.55 40.1561 7569 3331 7115 First Reading For Entire File 169 Last Reading For Entire File 7218.5 File Trailer • Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/07/17 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 • Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/07/17 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 167.0 3295.5 R15P 176.5 3305.5 R39P 176.5 3305.5 R27P 176.5 3305.5 RO9P 176.5 3305.5 EWXT 176.5 3305.5 ROPA 216.5 3346.0 LOG HEADER DATA DATE LOGGED: 05-JUN-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 3346.0 TOP LOG INTERVAL (FT) : 167.0 BOTTOM LOG INTERVAL (FT) : 3346.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 52.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11557008 EWR4 ELECTROMAG. RESIS. 4 10832534 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (F'�. . - .0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud . MUD DENSITY (LB/G) : 9.40 MUD VISCOSITY (S) : 190.0 MUD PH: 8. 9 MUD CHLORIDES (PPM) : 200 FLUID LOSS (C3) : • 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 5.500 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.310 121.0 MUD FILTRATE AT MT: 7.500 70.0 MUD CAKE AT MT: 5.000 70.0 NEUTRON TOOL MATRIX: ' MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : # REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined . Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 FET MWD030 HR 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 167 3346 1756.5 6359 167 3346 GR MWD030 API 27.8 98.1 50.061 6258 167 3295.5 FET MWD030 HR 0.09 7.59 0.955461 6259 176.5 3305.5 RPX MWD030 OHMM 6.75 247.54 52.7298 6259 176.5 3305.5 RPS MWD030 OHMM 7.27 938.93 91.0788 6259 176.5 3305.5 RPM MWD030 OHMM 7.32 1147.91 107.853 6259 176.5 3305.5 RPD MWD030 OHMM 7.86 2000 191.151 6259 176.5 3305.5 ROP MWD030 FPH 0.66 1027.12 169.419 6260 216.5 3346 First Reading For Entire File 167 Last Reading For Entire File 3346 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation '07/17 Maximum Physical Recordb 535 File Type LO Next File Name STSLIB.003 Physical EOF • File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/07/17 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH BTCS 3214.0 7076.0 BCSS 3214.0 7076.0 BVPS 3214.0 7076.0 DGRC 3296.0 7173.5 ADCL 3325.0 7131.0 TNNA 3325.0 7117.5 TNFA 3325.0 7117.5 APEL 3325.0 7131.0 TNPS 3325.0 7117.5 R39P 3325.0 7166.0 R27P 3325.0 7166.0 R15P 3325.0 7166.0 EWXT 3325.0 7166.0 ACDL 3325.0 7131.0 R09P 3325.0 7166.0 ROPA 3346.5 7221.0 AHSI 3348.0 7131.0 LOG HEADER DATA DATE LOGGED: 16-JUN-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88,47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7221.0 TOP LOG INTERVAL (FT) : 3346.0 BOTTOM LOG INTERVAL (FT) : 7221.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 9.0 MAXIMUM ANGLE: 18.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 11557009 EWR4 ELECTROMAG. RESIS. 4 11169387 CTN COMP THERMAL NEUTRON 11820594 BAT Bi-modal Acoustic 11236999 ALD Azimuthal Litho-Dens 224808 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (F�. . 3335.0 BOREHOLE CONDITIONS MUD TYPE: Polymer • MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 47.0 MUD PH: 10.1 MUD CHLORIDES (PPM) : 35000 FLUID LOSS (C3) : • 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : . 120 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 116.7 MUD FILTRATE AT MT: .110 70.0 MUD CAKE AT MT: .200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : # REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN i Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RHOB MWD040 G/CC 4 1 68 4 2 DRHO MWD040 G/CC 4 1 68 8 3 CALN MWD040 IN 4 1 68 12 4 PEF MWD040 B/E 4 1 68 16 5 DTC MWD040 USPF 4 1 68 20 6 SCRA MWD040 NONE 4 1 68 24 7 GR MWD040 API 4 1 68 28 8 DTSH MWD040 USPF 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 RPX MWD040 OHMM 4 1 68 40 11 RPS MWD040 OHMM 4 1 68 44 12 RPM MWD040 OHMM 4 1 68 48 13 RPD MWD040 OHMM 4 1 68 52 14 ROP MWD040 FPH 4 1 68 56 15 FCNT MWD040 CP30 4 1 68 60 16 NCNT MWD040 CP30 4 1 68 64 17 NPHI MWD040 PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3214 7221 5217.5 8015 3214 7221 RHOB MWD040 G/CC 0.762 2.961 2.24646 7613 3325 7131 DRHO MWD040 G/CC -4 .368 0.274 0.0491336 7613 3325 7131 CALN MWD040 IN 8.34 13.47 8.91279 7084 3348 7131 PEF MWD040 B/E 0.39 13.25 2.76427 7613 3325 7131 DTC MWD040 USPF 84.3511 172.626 121.949 7725 3214 7076 SCRA MWD040 NONE 1.4906 2.7313 2.01185 7704 3214 7076 GR MWD040 API 16 119.6 79.4215 7756 3296 7173.5 DTSH MWD040 USPF 160.5 338. 93 244.865 7704 3214 7076 FET L_,"'X40 HR 0.3 / 156.49 2.50726 7683 3325 7166 RPX MLvvv40 OHMM 0.15 1111.44 10.4117 7683 3325 7166 RPS MWD040 OHMM 0.2 1281.53 12.8967 7683 3325 7166 RPM MWD040 OHMM 0.28 1669.2 13.7051 7683 3325 7166 RPD MWD040 OHMM 4.54 2000 18.7633 7683 3325 7166 ROP MWD040 FPH 0.24 9515.36 119.225 7750 3346.5 7221 FCNT MWD040 CP30 389.22 2018.05 826.051 7586 3325 7117.5 NCNT MWD040 CP30 92760.3 153715 117286 7586 3325 7117.5 NPHI MWD040 PU 15.61 105.55 40.1642 7586 3325 7117.5 First Reading For Entire File 3214 Last Reading For Entire File 7221 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/07/17 Maximum Physical Record65535 File Type • LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 12/07/17 Origin . .STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/07/17 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services { Physical EOF Physical EOF End Of LIS File HALLIBURTON ..v141/ Sperry Drilling Surface Data Logging End of Well Report BRU 242-04 Client: ConocoPhillips Alaska Field: Beluga River Unit Rig: Doyon Arctic Fox Date: June 26, 2012 re tt. HALLIBURTON I Sperry Drilling TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Morning Reports 4. Bit Record 5. Mud Record 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: Final Logs Halliburton Log Viewer EMF Log Viewer EOW Report PDF Version ADI Backup Conoco Phillips Alaska,Inc. HALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Doyon Arctic Fox Well: BRU 242-04 Field: Beluga Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-283-20164-00-00 Sperry Job Number: AK-AM-0009498073 Spud Date: 1 June 2012 SDL Job Start Date: 12 June 2012 TD Date: 16 June 2012 Total Depth: 7221' MD, 6650' TVD SDL Release Date: 07 July 2012 North Reference: True Declination: 17.7551° Dip Angle: 74.021° Total Field Strength: 55689 nT Date Of Magnetic Data: 05 June 2012 Wellhead Coordinates N: North 61° 9' 56.649" Wellhead Coordinates W: West 151° 2' 53.928" Drill Floor Elevation 110.64' Ground Elevation: 92.14' Permanent Datum: Mean Sea Level SDL Engineers: Javian Ervin, Nick Istre SDL Sample Catchers: Dakota Novak, Nathan Van Kirk, Colton Roehl, Joshua Cloyd Company Geologist: Rick Levinson Company Representatives: Scott Heim, Donald Lutrick, Robert Wall, Jimmy Greco SSDS Unit Number: 115 ConocoPhillips Alaska,Inc. HALLIBURTON I Sperry Drilling DAILY SUMMARY 6/1/2012—Spudded BRU 242.04. 6/12/2012—SDL arrived on location for production section. Performed FIT to 15.7 ppg EMW. Prepared pits for fluid displacement. Displaced well to new 9.6 ppg Kla-Shield DF. Drilled to 3567' MD. Pulled out to the shoe for top drive trouble. Repaired top drive and ran back into the hole to 3561' MD. 6/13/2012 Drilled to 3944' MD. Circulated bottoms up. Pulled into the casing shoe for meeting. Tripped in the hole to 3316' MD to 3944' MD. Drilled ahead to 4588' MD. Gas: The max gas was 133 units at 3728' MD and the average drilling background gas was 11 units. 6/14/2012 Mid to 06:00 hours lost 15-20 barrels to the hole. Drilled to 5017' MD. Circulated bottoms up and pulled out of the hole to 3900' MD. After short trip, losses were reduced to 5-10 barrels per hour while drilling ahead and pumping at 400 gallons per minute. Rate of penetration at 100+ feet an hour. Drilled ahead to 5770' MD. Gas: The max gas was 340 units at 4230' MD and the average drilling background gas was 20 units. 6/15/2012 Drilled from 5770' MD to 6021' MD. Short tripped to 5005' MD. Ran back into the hole, washed down from 5957' MD to 6021' MD. Drilled ahead to 6586' MD. Gas: The max gas was 345 units at 5446' MD and the average drilling background gas was 272 units. 6/16/2012 Drilled from 6586' MD to 7221' MD TD. Circulated bottoms up one time. Pumped a high viscosity sweep. Circulated bottoms up two ties. Began pulling out of the hole for wiper trip to the shoe. Gas: The max gas was 442 units at 6272' MD and the average drilling background gas was 30 units. 6/17/2012 Finished wiper trip to the shoe. Circulated bottoms up. Ran back into the hole to 7221' MD. Double reamed out tight spots at 6410' MD 6942' MD, and 7029' MD. Washed down from 7093' MD to 7221' MD. Circulated bottoms up one time and pumped a high viscosity sweep and circulated bottoms up two times. Pulled out of the hole to 3253' MD. Ran back into the hole to 7156' MD with no problems. Washed and reamed to 7219' MD. Circulated bottoms up two times and conditioned hole. Began pulling out of the hole, working through tight spots. 6/18/2012 Finished pulling out of the hole to surface. Laid down BHA. Rigged up to run E-logs on drill pipe. ConocoPhillips Alaska,Inc. HALLI B U RTON I Sperry Drilling 6/19/2012 Rigged up wireline. Ran in the hole with wireline. Ran in the hole with convey logs from 4282' MD to 7000' MD. Began pulling out of the hole with wireline. 6/20/2012 Pulled out of the hole with logs. Rigged down wireline. Picked up and made up entry sub. Ran in the hole with logs to 3712' MD. 6/21/2012 Finished RDT logs. Pulled out of the hole and laid down logging tools. Picked up BHA and began running in to the hole to 896' MD. 6/22/2012 Continued running into the hole to 3346' MD. Slipped and cut drill line at shoe. Circulated and conditioned mud. Continued running into the hole to bottom. Washed and reamed from 6670' MD to 6746' MD and from 6966' MD to 7221' MD. Circulated and conditioned 9.7 ppg. Pulled out of the hole 5 stands. Checked for flow and pumped a dry job and pulled out of the hole. Wiper trip from 6872' MD to 6557' MD. Changed out upper rams. Picked up 7"test joint. 6/23/2012 Changed out pipe rams to 7"test. Dummy run 7" hanger. Ran in the hole to 3196' MD. Started losing returns. Pulled out of the hole sideways from 3196' MD to 2593' MD. Pumped LCM pill. Began pulling out of the hole. A trip gas of 323 units was seen while circulating. 6/24/2012 Finished pulling out of the hole, laying down 7" casing. Mixed 390 barrels of new mud. Rigged up and tested BOPs. Rigged down test equipment. Rigged up to run 7" casing. A trip gas of 57 units was seen while circulating. 6/25/2012 Ran in the hole with 7" casing. Break circulation at 10-12 joints. Circulated bottoms up at TD. Rigged up for cement job. 6/26/2012 Performed cement job as per plan. Partial loss of returns immediately before bumping the plug, 8 barrels lost to formation. Observed evidence of mud push and chemical wash returns to rock washer. Check valve not holding so hold pressure on well until cement is firm. Tested fill backside with mud. Back side tales less than 1 barrel of mud. A max trip gas of 96 units was seen and the average trip gas while circulating was 45 units. 6/27/2012 Prepared pit system and surface equipment. Flushed stack. Cleaned rig floor, draw works, mezzanine, beaverslide, and stairs. Pumped out cellar box. Pumped out remaining drilling fluid from pits. Inspected drilling line, drum install, and function test mixing pump. 6/28/2012 Continued to clean and prepare pits, surface equipment and lines using caustic mix/flush. First flush run complete. Built containment for`rain for rent' beside rock wash pits and placed the tanks in containment. 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Z 10Z/0£/9 !sd way 6u!seo „L}sal .!sd 0007 01 sou!! aoelJns led 00017 o} 6u!seo}sal o}JeNe8 dn pe66N 'CM ,E 6 6L o}elm] an u! pedd11 •}ueweoeids!p Jo}!uow pue aW A09E 0l alo14 all pp}n0 paddul 'aW ,9Z6L le 681 pue aloq 0141 u! du} pue yH8 dn amen •JeleM 14sO4 14}!nn sal!! pue }uawd!nbe eoelans 146noagl pegsnld ]H!d o!}sneo 11e esods!a 'H!d o!}snea 14}IM eu!I pue}uawd!nbe eoelans g6noaq} p014snEI Z 10Z/6Z/9 suW!4D AJJeds I N011:I118fl1VH HALLIBURTON I Sperry Drilling 7/07/2012 Made up hanger, land and tested hanger. Set packer. Monitored the well. Installed and tested BPV. Flushed lines, nippled down, began rigging down to move rig. SDL Released 07 July 2012 ConocoPhillips Alaska,Inc. ti Customer: Conoco Phillips Report#: 1 Well: BRU 242-04 Date: 06/12/2012 HALLIBU " TON Area: Beluga River Unit 04:00 Depth 3366' Location: Beluga Progress 24 hrs: 20' Sperry Drilling Rig: Doyon Arctic Fox Rig Activity: Displace 9.6 klashield Job No.: 50-283-20164-00-00 Report For: D. Luttrick/R.Wall , Daily Charges Total Charges: $43,995.00 M I ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr 0.0 0.0 Flow In •.m 0 SPP •si 0 Gas(units) 0 0 Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition De.th On Bot Hrs Ann Corr Av. Diam PWD Drillin• Min Ave Max 3366' 0.37 -- All Circ Min _Avg _Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out sect •.b E. cP lb/100ft2, ml/30min m•/1 % 3366' 9.60 9.60 67 22.5 20 15 7.0 8.00 200 6.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 _- 3346' -- - Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ---_----5—__ Gas Breakdown H2S Data Sample LineJMax: Avg: 1 Ambient Air Pit Room !Max: Avg: Gas(units) Chromatograph (ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E—-Early... 24 hr Recap: Slip and cut drill line.Wash down and drill out the float equipment and 20 feet of new hold.Drilled to 3366'.Circulate and Condition mud to a uniform in and out weight,to 9.6 PPG.Pull back into casing,rig up to perform FIT test.Use injection pump to perform FIT test to 18 PPG.Displace surface mud to 9.6 klashield at time of report. 1„: Logging Engineer: Javian Ervin * 10000 units=100%Gas In Air Customer: Conoco Phillips Report#: 2 Well: BRU 242-04 Date: 06/13/2012 HALLIBURTopj Area: Beluga River Unit 04:00 Depth 3756 Location: Beluga Progress 24 hrs: 390 Sperry Drilling Rig: Doyon Arctic Fox Rig Activity: Drilling Ahead Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP&Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr 120.0 147.0 3739' Flow In •.m 444 SPP •si Gas(units) 101 11 133 3728' Flow In(spm) 228 Gallons/stroke 0.0000 Hole Condition Depth On Bot Hrs Ann Corr Ave Diam Drillln• 9.72 Min 9.97 Av. 10.17 Max 3756' 5.2 PWD -- All Circ 9.48 Min 9.89 Avg 10.42 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt De.th ft in out sec/.t ..b E. pH Chlorides Cor Solids cP (Ib/100ft2, ml/30min m./I 3567' 9.60 9.60 48 1.0 12 20 5.6 10.30 37,000 6.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8,75 _------ Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) --- 10 —_ 80 Gas Breakdown I H2S Data (Sample Line'Max: !Avg: I Ambient Air Pit Room Max: Gas(units) ! PVT: I Depth ( ) Chromatograph (ppm) to to won+A1 to to to to to to to N` Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F---Formation...; E—-Early... 24 hr Recap: Drill to 3567'.Pull to shoe for top drive trouble.Repair top drive.Run into hole to 3561'.Currently drilling ahead at report �`� time. € 6ki' £7� k,; Logging Engineer: Javian Ervin 10000 units= 100% Gas In Air £, , Customer: Conoco Phillips Report#: 3 yy Well: BRU 242-04 Date: 06/14/2012 HA.L.L.IBURTON Area: Beluga River Unit 04:00 Depth 4768 Location: Beluga Progress 24 hrs: 1012 Sperry Oriehrip Rig: Doyon Arctic Fox Rig Activity: Drilling Ahead Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump &Flow Data: R.O.P. ft/hr 135.0 110.0 150.0 4758' Flow In •.m 364 SPP .si 1087 Gas(units) 161 20 340 4230' Flow In(spm) 364 Gallons/stroke 0.0000 Hole Condition Depth On Bot Hrs Ann Corr Av• Diam PWD Drillin. 9.85 Min 10.09 Av• 10.21 Max 4768' 16.4 -- All Ciro 9.48 Min 10.04 Avg 10.35 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De•th ft in out sed•t ••b E. cP (Ib/100ft2 m1/30min m 4 4588' 9.60 9.60 47 1.3 9 18 6.5 10.40 34,000 6.0 ,, BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 _------_— 77,7— ; a77 1 ,.,, ^ T Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) —_— 10 ---- 80 _-- Gas Breakdown H2S Data I Sample Line Max: 'Avg: I Ambient Air Pit Room IMax: Avg: I Gas(units) Chromatograph(ppm) Depth 1 to 1 to to 1 to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F—-Formation...; E—-Early... 24 hr Recap: Drill to 3944'.Circulate bottoms up.Pull into casing shoe for meeting.Trip into hole3316'to 3944'.Lost circulation at 4640'40bbls.Lost circulation at 4690',40 bbls.Currently drilling ahead losing 17 bbls and hour at report time. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air p I Customer: Conoco Phillips Report#: 4 Well: BRU 242-04 Date: 06/15/2012 HALL BURTON Area: Beluga River Unit 04:00 Depth 5950 _ .. Location: Beluga Progress 24 hrs: 1182 Sperry lin Rig: Doyon Arctic Fox Rig Activity: Drilling Ahead Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump &Flow Data: R.O.P. ft/hr 110.0 106.0 153.0 5908' Flow In ••m 400 SPP •si 1724 Gas(units) 45 272 345 5446' Flow In(spm) 400 Gallons/stroke 0.0000 Depth On 28.8 Hrs Ann Av. PWD All Circ 9.71 Min 10.20 Avg 10.46 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.thft in out sec/•t) sib E. cP Ib/100ft2, ml/30min m•/I 5770' 9.60 9.60 57 2.5 11 18 4.8 10.30 32,000 6.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 _------� Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 30 —__— 60 10 --- Gas Breakdown I H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F---Formation...; E—-Early... 24 hr Recap: Drilled to 5017'.Circulated bottoms up and pull out hole to 3900'.After short trip losses were reduced to 5-10,while drilling ahead and pumping 400 gpm.Currently drilling ahead at time of report. Logging Engineer: Javian Ervin " 10000 units=100%Gas In Air Customer: Conoco Phillips Report#: 5 Well: BRU 242-04 Date: 06/16/2012 114ALLIBURTONI Area: Beluga River Unit 04:00 Depth 6690 Location: Beluga Progress 24 hrs: 740 Sperry Drilling Rig: Doyon Arctic Fox Rig Activity: Drilling Ahead Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr 117.0 59.0 157.0 6507 Flow In •*m 459 SPP 'Si 2147 Gas(units) 33 30 442 6272' Flow In (spm) 459 Gallons/stroke 0.0000 De.th On Bot Hrs Ann Corr Av. Diam Drillin. 10.06 Min 10.29 Av. 10.44 Max Hole Condition PWD 6690' 39.7 All Circ 9.76 Min 10.24 Avg 10.48 Max IL Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids • De ith ft in out sec/st •.13 E. cP lb/100ft2, ml/30min me/I 6589' 9.70 9.70 60 3.5 13 21 4.4 10.20 35,000 10.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 20 70 10 Gas Breakdown I H2S Data I Sample Line'Max: 'Avg: I Ambient Air Pit Room IMax: lAvg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F—-Formation...; E—-Early... 24 hr Recap: Drilled from 5770'to 6021'.Short trip to 5005'.Run into hole slick.Wash down from 5957'to 6021'.Trip back into hole. Trip gas 190 units.Currently drilling at time of report. Logging Engineer: Javian Ervin * 10000 units=100%Gas In Air Customer: Conoco Phillips Report#: 6 Well: BRU 242-04 Date: 06/17/2012 H "�,LLIBURTON Area: Beluga River Unit 04:00 Depth 7721 .... Location: Beluga Progress 24 hrs: 531 Sperry Drifting Rig: Doyon Arctic Fox Rig Activity: Tripping in Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In ••m 0 SPP •si 0 Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition Death On Bot Hrs Ann Corr Av. Diam PWD Drillin. 0.00 Min 0.00 Av. 0.00 Max 7221' 45.5 -- All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Death ft in out sec/•t) ••b Es cP Ib/100ft2, ml/30min mill % 7221' 9.60 9.60 60 4.5 14 20 4.8 10.10 35,000 9.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' -- Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 40 60 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Drilled from 6586 to 7221'.Circulate bottoms up.Pump high vis sweep.Circulate bottoms up 2 times.Wiper trip to shoe at 3664'.Currently filling pipe and tripping to bottom. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air Customer: Conoco Phillips Report#: 7 Well: BRU 242-04 Date: 06/18/2012 I"IAL •.IBURTON Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: Sperry Grit inq Rig: Doyon Arctic Fox Rig Activity: Tripping out of hole Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump &Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In ••m 0 SPP .si 0 Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition De•th On Bot Hrs Ann Corr Av. Diam PWD Drillin• 0.00 Min 0.00 Av. 0.00 Max 7221' 45.5 -- All Ciro 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out sec/•t ••b Es cP (Ib/100ft2, ml/30min me/1 7221' 9.80 9.80 52 5.0 14 21 5.0 10.10 32,000 9.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221 3875' -- Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ------�---- Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...;F---Formation...; E—-Early... 24 hr Recap: Wiper trip to shoe.Circulate bottoms up.Run into hole to TD.Double ream out tight spots at 6410',6942 and 7029. Wash down from 7093'to 7221'.Circulate bottoms up. Pump hi viscosity sweep and circulate bottoms up 2x.Short trip to 3253' Run into hole to 7156'with no problems.Wash and ream to 7219'.Circulate and condition bottoms up 2x.Pull out hole for logs. Work back trough all tight spots from 6526'to 6337'.Currently pulling out of hole at report time. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air Customer: Conoco Phillips Report#: 8 1::::1 Well: BRU 242-04 Date: 06/19/2012 I"I A LL IBU RTON Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: .perry OH Mpg Rig: Doyon Arctic Fox Rig Activity: Tripping out of hole Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco VI Daily Charges Total Charges: til ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump&Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In •.m 0 SPP •si 0 Gas(units) 0 0 0 0' Flow In (spm) 0 Gallons/stroke 0.0000 Hole Condit. Death On Bot Hrs Ann Corr Av• Diam PWD Drillin. 0.00 Min 0.00 Ave 0.00 Max 7221' 45.5 -- All Circ 0.00 Min 0.00 Av. 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Deathft in out sec/•t ••bE• cP Ib/100ft2, ml/30min mill % 7221' 9.75 9.75 52 5.5 14 22 4.9 10.00 29,000 11.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' -- Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) -_-_--�_®--_ Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: lAvg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Finish pull out hole.Layed down BHA.Rigged up and run E-logs on Drill pipe.Currently running e-logs. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air r----- Customer: Conoco Phillips Report#: 9 Well: BRU 242-04 Date: 06/20/2012 HA L,L BURTOI Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: Sperry Drilling Rig: Doyon Arctic Fox Rig Activity: Sample pressures Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In •on 0 SPP •si 0 Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition Depth On Bot Hrs Ann Corr Av. Diam pm) Drillin• 0.00 Min 0.00 Av. 0.00 Max 7221' 45.5 -- All Circ 0.00 Min 0.00 Avg 0.00 Max P Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out sec/.t) ••b E. cP Ib/100ft2, ml/30min me/1 % I 7221' 9.80 9.80 52 5.5 15 20 4.9 10.00 30,000 10.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' -- Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ---_-----�� Gas Breakdown H2S Data I Sample Line IMax: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F---Formation...; E—-Early... 24 hr Recap: Rigged up wireline,side door entry sub,Xos.Run into hole with wireline with wireline BHA.Run into hole with convey logs from 4282'to 7000'.Pull out of hole to 5308'. Currently taking sample pressures. I Logging Engineer: Javian Ervin * 10000 units=100%Gas In Air Customer: Conoco Phillips Report#: 10 , Well: BRU 242-04 Date: 06/21/2012 H,AL,,,LJ URTON Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: '� Sperry Or atin Rig: Doyon Arctic Fox Rig Activity: `;l Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco io Daily Charges Total Charges: fir,.. ,., 04/,‘,..,`` ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: 11f R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In •.m 0 SPP • 0 Rql Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 0.0000 . Hole Condition De•th On Bot Hrs Ann Corr Av• Diam PWD Drillin• 0.00 Min 0.00 Av. 0.00 Max �) 7221' 45.5 -- All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De•thft in out (sec/.t) ••b E. cP (Ib/100ft2, m1/30min m./1 % , 7221' 9.80 9.80 53 5.5 14 21 4.6 10.00 29,000 11.0 =Ti< BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' -- Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line]Max: Avg: I Ambient Air Pit Room IMax: Avg: Gas(units) Chromatograph (ppm) Depth to RP Cal' to to to to to to to ti to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F—-Formation...; E---Early... 24 hr Recap: Pull out of hole with log from 6356 to 4775'.Pull out of hole from 4783'to 4282'.Rig down wireline side entry to relocate Pull out of hole from 4282'to 2865'.Pick up and make up side entry sub at 2834'.Run into hole with log from 2834'to 3712'. Currently contining going down with wireline log. Logging Engineer: Javian Ervin * 10000 units=100%Gas In Air Customer: Conoco Phillips Report#: 11 Well: BRU 242-04 Date: 06/22/2012 wg 111A L.IBURTON Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: Spor y Drilling Rig: Doyon Arctic Fox Rig Activity: Tripping in Job No.: 50-283-20164-00-00 Report For: D. Luttrick/J. Greco Daily Charges Total Charges: Of ROP&Gas: Current Avg 24 hr Max Max @ ft Current Pump &Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In •cm 0 SPP •si 0 Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition De•th On Bot Hrs Ann Corr Av. Diam PWD Drillin• 0.00 Min 0.00 ' 0.00 Max 7221' 45.5 -- All CirC 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De•th ft in out sec/.t ••b E• cP Ib/100ft2, m1/30min mill % 7221' 9.80 9.80 52 5.5 14 20 4.6 10.00 29,000 10.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' ---_ Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) _----_----�- Gas Breakdown I H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 'Avg: Gas(units) Chromatograph(ppm) Depth to to to to to IT to to to to Gas Type abreviations: BG-Background Gas;GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E---Early... 24 hr Recap: Finish RDT logs.Pull out of hole and lay down logging tools.Pick up BHA.Run into hole to 896.Currently tripping into hole. Logging Engineer: Javian Ervin * 10000 units=100%Gas In Air Customer: Conoco Phillips Report#: 11 Well: BRU 242-04 Date: 06/23/2012 HA .L BURTON Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: Sperry Drilling Rig: Doyon Arctic Fox Rig Activity: Tripping Out Job No.: 50-283-20164-00-00 Report For: S. Heim/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump&Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In ••m 0 SPP •si 0 Gas(units) 0 0 323 7188' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition Death On Bot Hrs Ann Corr Av• Diam PWD Drillin• 0.00 Min 0.00 Ave 0.00 Max 7221' 45.5 -- All Circ 0.00 Min 0.00 Avg 0.00 Max i 3 if' Mud Data: Density(ppg) Viscosity MBT .YP API Filt pH Chlorides Cor Solds Death ft in out sec/•t) •.b E. cP (Ib/100ft2, ml/30min m./1 % 7221' 9.65 9.65 53 5.5 13 21 4.3 10.00 30,000 10.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) _----_--_—_- Gas Breakdown I H2S Data I Sample Line(Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F---Formation...; E—-Early... 24 hr Recap: Run in hole to 3346'.Slip&cut drill line @ shoe.Circulate and Condition mud.Run into hole to TD;wash&ream from 6670'to 6746'and from 6966'to 7221'.Circulate and condition:9.7ppg and 2.5-3.0%lube.Pull out hole 5 stands;check flow;pump dry job and Pull out hole;wipe from 6872'to 6557'.Change out upper rams.Pick up 7"test Joint.Currently Tripping out hole. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air Customer: Conoco Phillips Report#: 13 Well: BRU 242-04 Date: 06/24/2012 111-LAL L IE3UR'TOPJ Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: Sperry Drilling Rig: Doyon Arctic Fox Rig Activity: Tripping Out Job No.: 50-283-20164-00-00 Report For: S. Heim/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump&Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In ••m 0 SPP 'Si 0 Gas(units) 0 8 57 3035' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition Death On Bot Hrs Ann Corr Av. Diam PWD Drillin• 0.00 Min 0.00 Av. 0.00 Max 7221' 45.5 -- All Circ 0.00 Min 0.00 Avg 0.00 Max /1 Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De.th ft in out sec/.t ••b Es cP (Ib/100ft2, ml/30min m./I % 7221' 9.70 9.70 51 5.0 13 18 4.5 10.00 29,000 9.0 BHA Run# Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' ---_ Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) ----- —_�—�� Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: 'Avg: Gas(units) Chromatograph(ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T---Trip...; F---Formation...; E—-Early... 24 hr Recap: Change pipe rams to 7",test.Dummy run 7"hanger.Run into hole to 3196'.Start losing return. Pull out hole sideways from 3196'to 2593'.Pump LCM pill.Currently Pulling out hole with casing. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air Customer: Conoco Phillips Report#: 14 Well: BRU 242-04 Date: 06/25/2012 I4,LLIBURTDN Area: Beluga River Unit 04:00 Depth 7721 Location: Beluga Progress 24 hrs: Sperry Drilling! Rig: Doyon Arctic Fox Rig Activity: Going in with casing Job No.: 50-283-20164-00-00 Report For: S. Heim/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In ••m 0 SPP •si 0 Gas(units) 0 0 0 0' Flow In(spm) 0 Gallons/stroke 0.0000 Hole Condition Depth On Bot Hrs Ann Corr Av. Diam PWD Drillin. 0.00 Min 0.00 Av. 0.00 Max 7221' 45.5 -- All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids De•th ft in out sec/•t ••b Es cP (Ib/100ft2, m1/30min m•/I % 7221' 9.70 9.70 54 2.0 13 18 4.9 10.50 31,000 8.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' -- Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) —��—_— —��-- Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: Gas(units) Chromatograph (ppm) Depth to to to to to to to to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F---Formation...; E---Early... 24 hr Recap: Finish Pulling out hole.Layed down 7"Casing.Mix 390 BBIs of new mud.Test BOP's.Rig down test equipment.Rig up and run 7"casing.Currently continuing running 7"casing down. Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air Customer: Conoco Phillips Report#: 15 Well: BRU 242-04 Date: 06/26/2012 HA U L IE3UR'ON Area: Beluga River Unit 04:00 Depth 7721 .. ,r Location: Beluga Progress 24 hrs: Sperry Or flini Rig: Doyon Arctic Fox Rig Activity: Cemeting Job No.: 50-283-20164-00-00 Report For: S. Heim/J. Greco Daily Charges Total Charges: ROP &Gas: Current Avg 24 hr Max Max @ ft Current Pump& Flow Data: R.O.P. ft/hr 0.0 0.0 0.0 0' Flow In ••m 0 SPP •si 0 Gas(units) 67 45 96 circ Flow In(spm) 0 Gallons/stroke 0.0000 De.th On Bot Hrs Ann Corr Av. Diam Drillin. 0.00 Min 0.00 Ave 0.00 Max Hole Condition 7221' 45.5 --PV1ID All Circ 0.00 Min 0.00 Avg 0.00 Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids a De•th ft in out sec/•t ••b Es cP Ib/100ft2, ml/30min ms/1 % 7221' 9.65 9.65 67 1.5 14 20 4.2 10.20 29,000 7.0 BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 400 PDC 8.75 45.50 3366' 7221' 3875' -- Lithology(%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) Gas Breakdown H2S Data I Sample Line Max: Av Ambient Air Pit Room 'Avg: P f � 9� 1 !Max:� Gas(units) Chromatograph(ppm) Depth to to to to to to to it to to Gas Type abreviations: BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas;T—-Trip...; F---Formation...; E---Early... 24 hr Recap: RIH w/7"casing.Break circ @ 10-12 jts.CIRC B/U @ TD.R/U for cement job.Currently cemeting at time of report. Wg Logging Engineer: Javian Ervin * 10000 units= 100%Gas In Air MALLIBURTON WELL NAME: BRU 242-04 LOCATION: Beluga OPERATOR: ConocoPhillips Alaska Inc. AREA: Beluga River Unit MUD CO: MI Swaco STATE: Alaska 'Sperry Drilling RIG: Doyon Arctic Fox SPUD: 1-Jun-12 SPERRY JOB: AK-AM-0009498073 TD: 16-Jun-12 BIT RECORD BHA# SDL Bit# Bit Type Bit Depth Depth Footage Bit TFA AVG WOB RPM SPP FLOW GPM Bit Grade Remarks RUN# Size In Out Hours ROP (max) (max) (max) (max) 1 100 1 NOV-M4686C 12.25 19 66 47 0.75 0.6995 63.0 1 60 90 177 O-o-NO-A-I-E-NO-BHA Clean out conductor 2 200 1 rr1 NOV-M4686C 12.25 66 217 151 2.53 0.6995 60.0 5 90 725 495 O-O-NO-A-I-E-NO-BHA Clean out to 217' 3 300 1r2 NOV-M4686C 12.25 217 3346 3129 31.87 0.6995 98.0 25 100 2250 580 1-2-WT-A-E-1-NO-TD Drill to casing point 4 400 2 NOV-DSF519D 8.75 3346 7221 3875 43.47 0.7731 89.0 15 110 2280 470 1-2-CT-G-X-I-NO-TD Drill to TD HALLI BURTON WELL NAME: BRU 242-04 LOCATION: Bulga OPERATOR: ConocoPhillips Alaska Inc AREA: Bulga River Unit Sperry Drilling MUD CO: MI Swaco STATE: Alaska RIG: Doyon Arctic Fox SPUD: 1-Jun-12 SPERRY JOB: AK-AM-0009498073 TD: 16-Jun-12 Water-Based Mud Record R600/R300/R200IR100/ Date Depth Wt Vis PV YP Gels Filt R6/R3 Cake Solids owWater Sd Pf/Mf pH Pm MBT Chlorides Hardness Remarks ft-MD ppg sec lb/100 Ib/100ft2 m/30m Rheometer 32nds % % % lb/gal mg/L Ca++ 1-Jun 65 - - - - - - - - - - - - - - - - - Picking up DP 2-Jun 617 8.7 340 23 58 30/48/49 11.0 103/80/71/58/33/33 31- 3.0 -/97 0.25 0.08/0.68 9 0.1 27.5 600 Tr Drilling Ahead 3-Jun 1813 8.80 121 24 34 15/35/47 9.4 82/58/49/37/15/13 2/- 4.0 -/96 0.50 0.10/0.40 8.7 0.1 25.0 200 40 Drilling Ahead 4-Jun 2757 9.30 175 21 53 27/45/51 8.0 95/74/62/49/26/24 2/- 5.5 -/95 0.50 0.10/0.40 8.6 0.1 30.0 150 40 Drilling Ahead 5-Jun 3346 9.40 212 37 72 23/47/58 7.2 146/109/93/71/27/23 2/- 6.0 -/94 0.75 0.10/0.40 8.5 0.1 35.0 200 20 POOH 6-Jun 3346 9.60 186 45 70 19/49/59 6.8 160/115/95/69/22/18 2/- 7.0 1/92 0.75 0.10/0.40 8.2 0.1 35.0 200 20 R/U to run casing 7-Jun 3346 9.60 60 21 14 5/7/10 6.8 56/35/27/20/5/4 2/- 6.5 Tr/94 0.50 0.00/0.40 7.6 - 25.0 300 20 R/D cement equipment 8-Jun 3346 9.50 67 20 15 4/7/8 7.0 55/35/27/20/4/3 2/- 6.0 Tr/94 0.33 0.00/0.40 8.0 - 22.5 200 20 M/U BOP 9-Jun 3346 9.50 67 20 15 4/7/8 7.0 55/35/27/20/4/3 2/- 6.0 Tr/94 0.33 0.00/0.41 8.0 - 22.5 200 20 Testing BOP 10-Jun 3346 9.50 67 20 15 4/7/9 7.0 55/35/27/20/4/4 2/- 6.0 Tr/94 0.33 0.00/0.42 8.0 - 22.5 200 20 CBU 11-Jun 3366 9.60 54 14 19 6/9/10 5.8 47/33/27/20/6/5 1/- 5.0 -/95 Tr 6.50/12.60 10.6 8.0 22.5 38000 40 FIT Testing 12-Jun 3567 9.60 48 12 20 6/8/8 5.6 44/32/26/20/6/5 1/- 6.0 -/94 Tr 4.60/9.60 10.3 5.4 1.0 37000 40 RIH 13-Jun 4588 9.60 47 9 18 5/6/7 6.4 36/27/22/16/6/4 1/- 6.0 1/93 Tr 5.60/10.50 10.4 6.2 1.3 34000 40 Drilling Ahead 14-Jun 5770 9.60 57 11 18 5/8/12 6.5 40/29/24/18/5/4 1/- 6.0 1/93 0.25 5.20/9.80 10.3 5.6 2.5 32000 40 Drilling Ahead 15-Jun 6589 9.70 60 13 21 6/9/14 5.2 47/34/28/20/6/5 1/- 10.0 2/88 0.33 5.80/8.50 10.2 5.2 3.5 35000 40 Tripping 16-Jun 7221 9.60 60 14 20 5/9/15 4.7 48/34/28/20/6/5 1/- 9.0 2/89 0.30 4.80/9.20 10.1 4.5 4.5 35000 40 Wiper trip to shoe 17-Jun 7221 9.60 _52 14 21 5/9/14 4.5 49/35/29/21/5/5 1/- 9.0 2/89 0.30 4.90/9.20 10.1 4.4 5.0 32000 40 POOH 18-Jun 7221 9.70 52 14 22 6/10/14 5.0 50/36/29/21/6/5 1/- 11.0 2/87 0.25 4.00/8.00 10.0 4.0 5.5 29000 40 Run E-logs 19-Jun 7221 9.90 52 15 20 6/10/15 5.0 50/35/29/21/6/5 1/- 10.0 2/88 0.25 4.00/8.20 10.0 4.1 5.5 30000 40 POOH w/Logs 20-Jun 7221 9.80 53 14 21 6/9/14 4.9 49/35/29/21/6/5 1/- 10.0 2/87 0.25 4.00/8.20 10.0 3.8 5.5 29000 40 Run E-logs 21-Jun 7221 9.80 52 14 20 6/8/12 4.6 48/34/28/20/6/5 1/- 10.0 2/88 0.25 4.00/8.30 10.0 4.1 5.5 29000 40 RIH 22-Jun 7221 9.80 _53 13 21 5/8/12 4.7 47/34/27/19/6/5 1/- 10.0 2/88 0.25 4.00/8.20 10.0 4.0 5.5 30000 40 P/U 7"Test Joint 23-Jun 7221 9.70 51 13 18 4/7/8 4.4 44/31/25/18/5/4 1/- 10.0 3/88 0.25 3.90/8.20 10.0 3.3 5.0 29000 40 POOH w/casing 24-Jun 7221 9.70 54 13 18 5/8/9 5.0 44/31/25/18/6/5 1/- 8.0 2/90 Tr 4.50/7.60 10.5 3.8 2.0 31000 40 RIH w/7"casing 25-Jun 7221 9.70 67 14 20 5/7/9 4.0 48/34/28/20/6/5 1/- 7.0 1/92 Tr 4.00/7.40 10.2 3.7 1.5 29000 40 CBU 26-Jun 7221 9.70 56 13 20 5/6/9 4.4 46/33/26/1/5/4 1/- 8.0 2/90 Tr 3.40/6.80 10.1 3.2 4.0 29000 40 Clean up&haul mud 27-Jun 7221 - - - - - - - - - - - - - - - - - Clean up&haul fluids 28-Jun 7221 - - - - - - - - - - - - - - - - Cont.Cleaning 29-Jun 7221 - - - - - - - - - - - - - - - - - R/U BJ Equipment 30-Jun 7221 - - - - - - - - - - - - - - - - - TOOH on TT 1-Jul 7221 9.80 29 - - - - - - - - - - - - - 166000 260 RIH w/TCP 2-Jul 7221 9.80 29 - - - - - - - - - - - - - 168000 260 UD PKR ASSY 3-Jul 7221 9.80 29 - - - - - - - - - - - - - 168000 260 L/D DP 4-Jul 7221 9.80 29 - - - - - - - - - - - 8.0 - 169000 280 R/U Wireline 5-Jul 7221 9.80 29 - 169000 260 R/U to RIH w/tubing 6-Jul 7221 9.80 29 - - - - - - - - - - - - - 167500 260 Space out completion 7-Jul 7221 - - - - - - - - - - - - - - - - - Rig down Casing Record 20"Conductor @ 107' 9 5/8"Surface @ 3,426'MD HALLI B U RTO N Sperry Drilling Formation Tops BRU 242-04 KB = 18.5' Formation/Unit MD TVD TVDss Injection Zone 3430 2919 2900.5 Sterling A 3649 3132 3113.5 Sterling B 3847 3326 3307.5 Sterling C 3997 3474 3455.5 Beluga D 4166 3640 3621.5 Beluga E 4434 3904 3885.5 Beluga F 4802 4266 4247.5 Beluga G 5370 4825 4806.5 Beluga H 5773 5222 5203.5 Beluga I 6530 5968 5949.5 Beluga J 7112 6542 6523.5 TD 7221 6650 6631.5 ConocoPhillips (Alaska) Inc. Definitive Survey Report 7 Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 t. Project: '- Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True 1 Welibore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Project Beluga River Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well BRU 242-04 Well Position +N/-S 0.00 ft Northing: 2,619,715.42 ft Latitude: 61°9'58.660 N +E/-W 0.00 ft Easting: 315,291.27 ft Longitude: 151°2'45.874 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.14ft Welibore BRU 242-04 Magnetics Model Name ' Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 6/17/2012 17.74 74.02 55,688 Design BRU 242-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 18.50 0.00 0.00 190.88 Survey Program Date 7/6/2012 -From To (ft) (ft) Survey(Weilbore) Tool Name Description Survey Date 148.21 3,254.78 BRU 242-04(BRU 242-04) MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C7/6/2012 12:0C 3,352.40 7,175.95 BRU 242-04(BRU 242-04) MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C7/6/2012 12:OC Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -92.14 0.00 0.00 2,619,715.42 315,291.27 0.00 0.00 UNDEFINED 148.21 0.55 340.24 148.21 37.57 0.59 -0.21 2,619,716.01 315,291.07 0.42 -0.54 MWD+SCC+SAG(1) 185.05 0.39 327.89 185.05 74.41 0.86 -0.34 2,619,716.28 315,290.95 0.51 -0.78 MWD+SCC+SAG(1) 244.05 0.28 329.34 244.05 133.41 1.15 -0.52 2,619,716.58 315,290.77 0.19 -1.03 MWD+SCC+SAG(1) 309.29 0.14 260.19 309.29 198.65 1.28 -0.68 2,619,716.70 315,290.62 0.41 -1.13 MWD+SCC+SAG(1) 369.72 0.99 225.52 369.71 259.07 0.90 -1.12 2,619,716.33 315,290.17 1.45 -0.67 MWD+SCC+SAG(1) 429.41 2.47 214.78 429.37 318.73 -0.52 -2.22 2,619,714.93 315,289.04 2.53 0.93 MWD+SCC+SAG(1) 486.29 3.52 205.16 486.18 375.54 -3.11 -3.67 2,619,712.37 315,287.56 2.04 3.74 MWD+SCC+SAG(1) 548.08 4.37 203.40 547.82 437.18 -6.98 -5.41 2,619,708.52 315,285.76 1.39 7.88 MWD+SCC+SAG(1) 615.28 5.54 205.30 614.77 504.13 -12.27 -7.81 2,619,703.28 315,283.27 1.76 13.52 MWD+SCC+SAG(1) 676.29 6.48 206.32 675.44 564.80 -18.02 -10.60 2,619,697.57 315,280.39 1.55 19.69 MWD+SCC+SAG(1) 741.28 7.69 202.75 739.93 629.29 -25.31 -13.90 2,619,690.33 315,276.97 1.98 27.48 MWD+SCC+SAG(1) 804.16 9.11 197.97 802.14 691.50 -33.93 -17.07 2,619,681.77 315,273.67 2.51 36.54 MWD+SCC+SAG(1) 7/6/2012 10:34:49AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) P Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True 4 Wel!bore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design; BRU 242-04 Database: CPAI EDM Production Map Map` Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Easting DLS Section (ft) (°), (°) (ft) (ft) (ft) (ft) (ft) (ft) (°11001 (ft) Survey Tool Name 867.08 12.55 196.10 863.93 753.29 -45.24 -20.50 2,619,670.52 315,270.05 5.49 48.29 MWD+SCC+SAG(1) 898.93 14.64 197.72 894.88 784.24 -52.40 -22.68 2,619,663.39 315,267.75 6.67 55.74 MWD+SCC+SAG(1) 926.93 16.09 197.63 921.88 811.24 -59.47 -24.94 2,619,656.36 315,265.39 5.18 63.10 MWD+SCC+SAG(1) 962.10 17.36 199.18 955.56 844.92 -69.07 -28.14 2,619,646.81 315,262.04 3.83 73.14 MWD+SCC+SAG(1) 990.49 18.57 198.26 982.57 871.93 -77.36 -30.94 2,619,638.57 315,259.10 4.38 81.81 MWD+SCC+SAG(1) 1,053.84 20.14 196.89 1,042.34 931.70 -97.38 -37.27 2,619,618.65 315,252.45 2.58 102.66 MWD+SCC+SAG(1) 1,116.87 22.03 195.58 1,101.14 990.50 -119.15 -43.60 2,619,596.99 315,245.77 3.09 125.24 MWD+SCC+SAG(1) 1,178.50 24.75 194.16 1,157.71 1,047.07 -142.80 -49.86 2,619,573.45 315,239.13 4.51 149.64 MWD+SCC+SAG(1) 1,243.17 28.78 192.87 1,215.44 1,104.80 -171.11 -56.65 2,619,545.24 315,231.90 6.30 178.73 MWD+SCC+SAG(1) 1,279.06 30.84 192.44 1,246.57 1,135.93 -188.52 -60.55 2,619,527.90 315,227.72 5.77 196.56 MWD+SCC+SAG(1) 1,305.36 31.68 192.52 1,269.06 1,158.42 -201.84 -63.50 2,619,514.63 315,224.55 3.20 210.20 MWD+SCC+SAG(1) 1,371.15 32.31 192.74 1,324.85 1,214.21 -235.86 -71.12 2,619,480.74 315,216.39 0.97 245.04 MWD+SCC+SAG(1) 1,433.89 34.65 193.02 1,377.18 1,266.54 -269.59 -78.84 2,619,447.13 315,208.13 3.74 279.63 MWD+SCC+SAG(1) 1,495.96 35.89 192.60 1,427.85 1,317.21 -304.54 -86.79 2,619,412.32 315,199.63 2.04 315.45 MWD+SCC+SAG(1) 1,558.62 37.52 192.32 1,478.09 1,367.45 -341.11 -94.86 2,619,375.89 315,190.97 2.62 352.89 MWD+SCC+SAG(1) 1,621.24 41.74 190.68 1,526.31 1,415.67 -380.24 -102.80 2,619,336.89 315,182.41 6.94 392.81 MWD+SCC+SAG(1) 1,653.10 44.26 189.55 1,549.61 1,438.97 -401.63 -106.61 2,619,315.56 315,178.26 8.27 414.54 MWD+SCC+SAG(1) 1,684.76 46.24 188.08 1,571.90 1,461.26 -423.85 -110.05 2,619,293.41 315,174.46 7.07 437.01 MWD+SCC+SAG(1) 1,718.58 46.87 189.29 1,595.15 1,484.51 -448.12 -113.76 2,619,269.20 315,170.37 3.20 461.54 MWD+SCC+SAG(1) 1,747.34 47.30 190.03 1,614.74 1,504.10 -468.89 -117.29 2,619,248.50 315,166.50 2.41 482.60 MWD+SCC+SAG(1) 1,810.50 48.65 190.54 1,657.02 1,546.38 -515.05 -125.67 2,619,202.48 315,157.39 2.22 529.51 MWD+SCC+SAG(1) 1,869.68 51.22 190.73 1,695.11 1,584.47 -559.56 -134.03 2,619,158.11 315,148.32 4.35 574.80 MWD+SCC+SAG(1) 1,936.77 52.31 191.13 1,736.63 1,625.99 -611.30 -144.03 2,619,106.54 315,137.50 1.69 627.50 MWD+SCC+SAG(1) 1,995.43 51.48 191.09 1,772.83 1,662.19 -656.59 -152.92 2,619,061.39 315,127.88 1.42 673.65 MWD+SCC+SAG(1) 2,059.55 50.23 191.10 1,813.30 1,702.66 -705.39 -162.49 2,619,012.76 315,117.53 1.95 723.38 MWD+SCC+SAG(1) 2,121.88 49.37 190.17 1,853.53 1,742.89 -752.18 -171.28 2,618,966.12 315,108.00 1.79 770.99 MWD+SCC+SAG(1) 2,185.18 48.61 191.25 1,895.07 1,784.43 -799.11 -180.15 2,618,919.34 315,098.37 1.76 818.75 MWD+SCC+SAG(1) 2,248.43 47.96 190.67 1,937.16 1,826.52 -845.46 -189.13 2,618,873.14 315,088.66 1.23 865.96 MWD+SCC+SAG(1) 2,310.69 47.27 190.13 1,979.13 1,868.49 -890.69 -197.43 2,618,828.05 315,079.63 1.28 911.95 MWD+SCC+SAG(1) 2,375.67 45.68 189.16 2,023.88 1,913.24 -937.14 -205.33 2,618,781.74 315,070.99 2.68 959.05 MWD+SCC+SAG(1) 2,438.98 43.64 188.39 2,068.91 1,958.27 -981.11 -212.12 2,618,737.88 315,063.50 3.33 1,003.52 MWD+SCC+SAG(1) 2,501.78 42.08 188.73 2,114.94 2,004.30 -1,023.35 -218.48 2,618,695.75 315,056.47 2.51 1,046.20 MWD+SCC+SAG(1) 2,563.56 39.80 189.00 2,161.61 2,050.97 -1,063.35 -224.72 2,618,655.86 315,049.59 3.70 1,086.65 MWD+SCC+SAG(1) 2,627.46 37.10 189.53 2,211.65 2,101.01 -1,102.56 -231.11 2,618,616.76 315,042.58 4.26 1,126.37 MWD+SCC+SAG(1) 2,690.89 35.80 189.16 2,262.67 2,152.03 -1,139.75 -237.23 2,618,579.68 315,035.86 2.08 1,164.04 MWD+SCC+SAG(1) 2,751.40 34.54 188.77 2,312.13 2,201.49 -1,174.18 -242.66 2,618,545.34 315,029.88 2.12 1,198.87 MWD+SCC+SAG(1) 2,815.13 33.29 188.68 2,365.01 2,254.37 -1,209.32 -248.06 2,618,510.29 315,023.92 1.96 1,234.41 MWD+SCC+SAG(1) 2,877.83 32.04 190.06 2,417.80 2,307.16 -1,242.71 -253.56 2,618,477.00 315,017.89 2.32 1,268.23 MWD+SCC+SAG(1) 2,941.54 30.41 190.45 2,472.28 2,361.64 -1,275.21 -259.44 2,618,444.60 315,011.49 2.58 1,301.26 MWD+SCC+SAG(1) 3,005.33 28.83 189.59 2,527.73 2,417.09 -1,306.25 -264.93 2,618,413.65 315,005.51 2.56 1,332.78 MWD+SCC+SAG(1) 7/62012 10:34:49AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True Weilbore: BRU 242-04 Survey Calculation Method: Minimum Curvature BRU 242-04 Database: CPAI EDM Production Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section Survey Tool Name (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) 3,068.83 27.01 189.36 2,583.84 2,473.20 -1,335.58 -269.82 2,618,384.41 315,000.14 2.87 1,362.50 MWD+SCC+SAG(1) 3,129.56 25.44 189.95 2,638.31 2,527.67 -1,362.04 -274.32 2,618,358.03 314,995.22 2.62 1,389.33 MWD+SCC+SAG(1) 3,191.47 23.51 190.13 2,694.66 2,584.02 -1,387.29 -278.79 2,618,332.85 314,990.35 3.12 1,414.98 MWD+SCC+SAG(1) 3,254.78 21.35 189.97 2,753.17 2,642.53 -1,411.07 -283.01 2,618,309.14 314,985.75 3.41 1,439.13 MWD+SCC+SAG(1) 3,352.40 18.54 190.95 2,844.93 2,734.29 -1,443.82 -289.03 2,618,276.49 314,979.20 2.90 1,472.42 MWD+SCC+SAG(2) 3,400.42 17.02 190.29 2,890.66 2,780.02 -1,458.23 -291.74 2,618,262.13 314,976.27 3.19 1,487.09 MWD+SCC+SAG(2) 3,463.87 13.80 187.04 2,951.82 2,841.18 -1,474.88 -294.32 2,618,245.52 314,973.42 5.25 1,503.93 MWD+SCC+SAG(2) 3,498.71 12.72 185.50 2,985.73 2,875.09 -1,482.82 -295.20 2,618,237.59 314,972.41 3.26 1,511.89 MWD+SCC+SAG(2) 3,525.12 12.57 185.74 3,011 50 2,900.86 -1,488.58 -295.77 2,618,231.85 314,971.75 0.60 1,517.65 MWD+SCC+SAG(2) 3,589.05 12.49 190.22 3,073.91 2,963.27 -1,502.30 -297.69 2,618,218.16 314,969.61 1.53 1,531.49 MWD+SCC+SAG(2) 3,652.03 12.72 190.70 3,135.37 3,024.73 -1,515.82 -300.19 2,618,204.69 314,966.90 0.40 1,545.23 MWD+SCC+SAG(2) 3,715.94 11.18 188.92 3,197.89 3,087.25 -1,528.85 -302.45 2,618,191.69 314,964.43 2.48 1,558.46 MWD+SCC+SAG(2) 3,778.73 10.68 192.05 3,259.54 3,148.90 -1,540.56 -304.61 2,618,180.02 314,962.08 1.24 1,570.36 MWD+SCC+SAG(2) 3,842.33 10.90 192.18 3,322.02 3,211.38 -1,552.20 -307.11 2,618,168.42 314,959.40 0.35 1,582.27 MWD+SCC+SAG(2) 3,902.78 10.78 192.10 3,381.39 3,270.75 -1,563.31 -309.50 2,618,157.35 314,956.83 0.20 1,593.63 MWD+SCC+SAG(2) 3,966.83 10.02 192.22 3,444.39 3,333.75 -1,574.62 -311.94 2,618,146.09 314,954.21 1.19 1,605.19 MWD+SCC+SAG(2) 4,030.43 10.17 191.99 3,507.00 3,396.36 -1,585.52 -314.27 2,618,135.23 314,951.70 0.24 1,616.34 MWD+SCC+SAG(2) 4,090.95 10.33 191.83 3,566.56 3,455.92 -1,596.05 -316.50 2,618,124.73 314,949.31 0.27 1,627.10 MWD+SCC+SAG(2) 4,154.77 10.29 191.10 3,629.35 3,518.71 -1,607.25 -318.77 2,618,113.57 314,946.86 0.21 1,638.53 MWD+SCC+SAG(2) 4,216.22 10.11 192.57 3,689.82 3,579.18 -1,617.90 -321.00 2,618,102.96 314,944.46 0.52 1,649.41 MWD+SCC+SAG(2) 4,281.50 10.03 190.05 3,754.10 3,643.46 -1,629.09 -323.24 2,618,091.81 314,942.04 0.69 1,660.82 MWD+SCC+SAG(2) 4,344.50 10.04 190.00 3,816.14 3,705.50 -1,639.90 -325.15 2,618,081.03 314,939.96 0.02 1,671.79 MWD+SCC+SAG(2) 4,408.55 9.79 189.42 3,879.23 3,768.59 -1,650.77 -327.01 2,618,070.19 314,937.93 0.42 1,682.82 MWD+SCC+SAG(2) 4,471.09 10.22 190.67 3,940.82 3,830.18 -1,661.47 -328.91 2,618,059.52 314,935.86 0.77 1,693.68 MWD+SCC+SAG(2) 4,535.21 10.40 191.37 4,003.90 3,893.26 -1,672.73 -331.10 2,618,048.30 314,933.48 0.34 1,705.16 MWD+SCC+SAG(2) 4,597.75 10.15 191.15 4,065.44 3,954.80 -1,683.67 -333.28 2,618,037.39 314,931.13 0.40 1,716.31 MWD+SCC+SAG(2) 4,660.16 10.29 191.41 4,126.86 4,016.22 -1,694.53 -335.44 2,618,026.57 314,928.79 0.24 1,727.39 MWD+SCC+SAG(2) 4,723.88 10.33 191.43 4,189.55 4,078.91 -1,705.71 -337.70 2,618,015.43 314,926.35 0.06 1,738.79 MWD+SCC+SAG(2) 4,787.12 10.25 192.05 4,251.77 4,141.13 -1,716.77 -340.00 2,618,004.41 314,923.88 0.22 1,750.09 MWD+SCC+SAG(2) 4,848.17 10.01 191.12 4,311.87 4,201.23 -1,727.29 -342.16 2,617,993.93 314,921.55 0.48 1,760.82 MWD+SCC+SAG(2) 4,910.58 9.92 190.24 4,373.34 4,262.70 -1,737.90 -344.16 2,617,983.35 314,919.38 0.28 1,771.62 MWD+SCC+SAG(2) 4,973.22 9.82 189.30 4,435.05 4,324.41 -1,748.48 -345.98 2,617,972.80 314,917.39 0.30 1,782.36 MWD+SCC+SAG(2) 5,037.12 10.07 192.15 4,497.99 4,387.35 -1,759.32 -348.04 2,617,962.00 314,915.16 0.86 1,793.39 MWD+SCC+SAG(2) 5,101.01 10.24 193.48 4,560.88 4,450.24 -1,770.30 -350.54 2,617,951.06 314,912.49 0.45 1,804.65 MWD+SCC+SAG(2) 5,162.48 10.35 192.34 4,621.36 4,510.72 -1,781.01 -352.99 2,617,940.39 314,909.86 0.38 1,815.62 MWD+SCC+SAG(2) 5,224.97 10.32 192.41 4,682.84 4,572.20 -1,791.96 -355.39 2,617,929.48 314,907.29 0.05 1,826.83 MWD+SCC+SAG(2) 5,286.63 10.15 191.97 4,743.52 4,632.88 -1,802.67 -357.71 2,617,918.81 314,904.80 0.30 1,837.78 MWD+SCC+SAG(2) 5,350.49 10.03 193.36 4,806.39 4,695.75 -1,813.58 -360.16 2,617,907.94 314,902.18 0.43 1,848.97 MWD+SCC+SAG(2) 5,413.09 9.96 193.38 4,868.04 4,757.40 -1,824.16 -362.67 2,617,897.41 314,899.50 0.11 1,859.82 MWD+SCC+SAG(2) 5,476.24 9.73 193.47 4,930.26 4,819.62 -1,834.66 -365.18 2,617,886.95 314,896.82 0.37 1,870.61 MWD+SCC+SAG(2) 7/6/2012 10:34:49AM Page 4 COMPASS 2003.16 Build 69 F ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Site: Beluga River MD Reference: Rig:242-04 @ 110.64ft(Artic Fox) Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) , (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name. 5,539.38 9.57 193.91 4,992.51 4,881.87 -1,844.94 -367.68 2,617,876.70 314,894.15 0.28 1,881.18 MWD+SCC+SAG(2) 5,602.35 10.08 191.87 5,054.55 4,943.91 -1,855.42 -370.08 2,617,866.27 314,891.59 0.98 1,891.92 MWD+SCC+SAG(2) 5,665.31 10.15 190.15 5,116.53 5,005.89 -1,866.27 -372.19 2,617,855.45 314,889.31 0.49 1,902.97 MWD+SCC+SAG(2) 5,728.58 10.02 190.04 5,178.83 5,068.19 -1,877.18 -374.13 2,617,844.58 314,887.19 0.21 1,914.05 MWD+SCC+SAG(2) 5,791.64 9.96 189.45 5,240.93 5,130.29 -1,887.96 -375.98 2,617,833.83 314,885.17 0.19 1,924.99 MWD+SCC+SAG(2) 5,853.67 9.88 189.15 5,302.03 5,191.39 -1,898.50 -377.71 2,617,823.31 314,883.27 0.15 1,935.67 MWD+SCC+SAG(2) 5,915.71 9.84 189.70 5,363.16 5,252.52 -1,908.98 -379.45 2,617,812.86 314,881.37 0.16 1,946,29 MWD+SCC+SAG(2) 5,980.28 9.76 189.45 5,426.79 5,316.15 -1,919.82 -381.27 2,617,802.06 314,879.37 0.14 1,957.28 MWD+SCC+SAG(2) 6,042.35 9.45 187.97 5,487.98 5,377.34 -1,930.06 -382.85 2,617,791.85 314,877.63 0.64 1,967.63 MWD+SCC+SAG(2) 6,105.54 9.16 187.79 5,550.34 5,439.70 -1,940.18 -384.25 2,617,781.75 314,876.07 0.46 1,977.83 MWD+SCC+SAG(2) 6,167.75 9.02 188.91 5,611.77 5,501.13 -1,949.90 -385.67 2,617,772.05 314,874.49 0.36 1,987.65 MWD+SCC+SAG(2) 6,231.97 9.55 190.39 5,675.15 5,564.51 -1,960.11 -387.41 2,617,761.87 314,872.58 0.91 1,998.01 MWD+SCC+SAG(2) 6,293.76 9.88 189.95 5,736.05 5,625.41 -1,970.38 -389.25 2,617,751.64 314,870.58 0.55 2,008.43 MWD+SCC+SAG(2) 6,356.77 10.37 189.96 5,798.08 5,687.44 -1,981.29 -391.17 2,617,740.76 314,868.49 0.78 2,019.51 MWD+SCC+SAG(2) 6,419.72 10.38 189.51 5,860.00 5,749.36 -1,992.46 -393.09 2,617,729.62 314,866.40 0.13 2,030.84 MWD+SCC+SAG(2) 6,482.50 10.37 189.45 5,921.76 5,811.12 -2,003.61 -394.95 2,617,718.50 314,864.36 0.02 2,042.14 MWD+SCC+SAG(2) 6,545.82 10.18 189.21 5,984.06 5,873.42 -2,014.76 -396.78 2,617,707.39 314,862.35 0.31 2,053.43 MWD+SCC+SAG(2) 6,608.40 9.93 188.86 6,045.68 5,935.04 -2,025.55 -398.50 2,617,696.63 314,860.46 0.41 2,064.36 MWD+SCC+SAG(2) 6,672.94 10.02 188.63 6,109.24 5,998.60 -2,036.60 -400.19 2,617,685.61 314,858.58 0.15 2,075.53 MWD+SCC+SAG(2) 6,734.96 9.85 187.08 6,170.34 6,059.70 -2,047.20 -401.66 2,617,675.03 314,856.95 0.51 2,086.21 MWD+SCC+SAG(2) 6,796.88 9.77 186.52 6,231.35 6,120.71 -2,057.67 -402.91 2,617,664.58 314,855.53 0.20 2,096.73 MWD+SCC+SAG(2) 6,860.77 9.76 186.88 6,294.31 6,183.67 -2,068.43 -404.17 2,617,653.84 314,854.10 0.10 2,107.54 MWD+SCC+SAG(2) 6,923.80 9.81 186.35 6,356.43 6,245.79 -2,079.07 -405.41 2,617,643.22 314,852.69 0.16 2,118.22 MWD+SCC+SAG(2) 6,987.55 9.79 186.26 6,419.25 6,308.61 -2,089.86 -406.60 2,617,632.46 314,851.33 0.04 2,129.04 MWD+SCC+SAG(2) 7,049.72 9.43 184.50 6,480.54 6,369.90 -2,100.19 -407.57 2,617,622.14 314,850.19 0.75 2,139.37 MWD+SCC+SAG(2) 7,113.24 9.28 182.87 6,543.22 6,432.58 -2,110.49 -408.24 2,617,611.85 314,849.36 0.48 2,149.61 MWD+SCC+SAG(2) 7,175.95 9.06 182.67 6,605.13 6,494.49 -2,120.48 408.72 2,617,601.88 314,848.72 0.35 2,159.51 MWD+SCC+SAG(2) 7,221.00 9.06 182.67 6,649.62 6,538.98 -2,127.56 409.05 2,617,594.80 314,848.27 0.00 2,166.53 PROJECTED to TD 7/612012 10:34:49AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. T------ , . . ________--- . - -- --, Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox; I Site: Beluga River MD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox; Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Project Beluga River,Alaska,USA Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well BRU 242-04 Well Position +N/-S 0.00 ft Northing: 2,619,476.00 ft Latitude: 61°9'56.649 N +E/-W 0.00 ft Easting: 1,455,318.00ft Longitude: 151°2'53.907 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.14ft Wellbore BRU 242-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 6/16/2012 17.74 74.02 55,688 Design BRU 242-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 18.50 0.00 0.00 191.13 Survey Program Date 7/6/2012 From To (ft) (ft) Survey(Wellbore); Tool Name Description Survey Date 148.21 3,254.78 BRU 242-04(BRU 242-04) MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C6/7/2012 12:0C 3,352.40 7,175.95 BRU 242-04(BRU 242-04) MWD+SCC+SAG MWD+Short Collar correction+BHA SAG C6/7/2012 12:0C Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (') (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -92.14 0.00 0.00 2,619,476.00 1,455,318.00 0.00 0.00 UNDEFINED 148.21 0.55 340.24 148.21 37.57 0.59 -0.21 2,619,476.59 1,455,317.80 0.42 -0.53 MWD+SCC+SAG(1) 185.05 0.39 327.89 185.05 74.41 0.86 -0.34 2,619,476.86 1,455,317.68 0.51 -0.78 MWD+SCC+SAG(1) 244.05 0.28 329.34 244.05 133.41 1.15 -0.52 2,619,477.16 1,455,317.50 0.19 -1.03 MWD+SCC+SAG(1) 309.29 0.14 260.19 309.29 198.65 1.28 -0.68 2,619,477.29 1,455,317.34 0.41 -1.12 MWD+SCC+SAG(1) 369.72 0.99 225.52 369.71 259.07 0.90 -1.12 2,619,476.92 1,455,316.89 1.45 -0.66 MWD+SCC+SAG(1) 429.41 2.47 214.78 429.37 318.73 -0.52 -2.22 2,619,475.52 1,455,315.77 2.53 0.94 MWD+SCC+SAG(1) 486.29 3.52 205.16 486.18 375.54 -3.11 -3.67 2,619,472.95 1,455,314.29 2.04 3.76 MWD+SCC+SAG(1) 548.08 4.37 203.40 547.82 437.18 -6.98 -5.41 2,619,469.10 1,455,312.48 1.39 7.90 MWD+SCC+SAG(1) 615.28 5.54 205.30 614.77 504.13 -12.27 -7.81 2,619,463.86 1,455,309.99 1.76 13.54 MWD+SCC+SAG(1) 676.29 6.48 206.32 675.44 564.80 -18.02 -10.60 2,619,458.16 1,455,307.12 1.55 19.72 MWD+SCC+SAG(1) 741.28 7.69 202.75 739.93 629.29 -25.31 -13.90 2,619,450.91 1,455,303.69 1.98 27.52 MWD+SCC+SAG(1) 804.16 9.11 197.97 802.14 691.50 -33.93 -17.07 2,619,442.35 1,455,300.39 2.51 36.58 MWD+SCC+SAG(1) 7/6/2012 10:22:38AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox;: Site: Beluga River MD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox; Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 867.08 12.55 196.10 863.93 753.29 -45.24 -20.50 2,619,431.10 1,455,296.78 5.49 48.34 MWD+SCC+SAG(1) 898.93 14.64 197.72 894.88 784.24 -52.40 -22.68 2,619,423.98 1,455,294.48 6.67 55.79 MWD+SCC+SAG(1) 926.93 16.09 197.63 921.88 811.24 -59.47 -24.94 2,619,416.94 1,455,292.12 5.18 63.16 MWD+SCC+SAG(1) 962.10 17.36 199.18 955.56 844.92 -69.07 -28.14 2,619,407.40 1,455,288.76 3.83 73.20 MWD+SCC+SAG(1) 990.49 18.57 198.26 982.57 871.93 -77.36 -30.94 2,619,399.15 1,455,285.82 4.38 81.88 MWD+SCC+SAG(1) 1,053.84 20.14 196.89 1,042.34 931.70 -97.38 -37.27 2,619,379.24 1,455,279.17 2.58 102.74 MWD+SCC+SAG(1) 1,116.87 22.03 195.58 1,101.14 990.50 -119.15 -43.60 2,619,357.57 1,455,272.50 3.09 125.32 MWD+SCC+SAG(1) 1,178.50 24.75 194.16 1,157.71 1,047.07 -142.80 -49.86 2,619,334.03 1,455,265.86 4.51 149.74 MWD+SCC+SAG(1) 1,243.17 28.78 192.87 1,215.44 1,104.80 -171.11 -56.65 2,619,305.83 1,455,258.62 6.30 178.83 MWD+SCC+SAG(1) 1,279.06 30.84 192.44 1,246.57 1,135.93 -188.52 -60.55 2,619,288.49 1,455,254.44 5.77 196.66 MWD+SCC+SAG(1) 1,305.36 31.68 192.52 1,269.06 1,158.42 -201.84 -63.50 2,619,275.21 1,455,251.28 3.20 210.31 MWD+SCC+SAG(1) 1,371.15 32.31 192.74 1,324.85 1,214.21 -235.86 -71.12 2,619,241.33 1,455,243.11 0.97 245.15 MWD+SCC+SAG(1) 1,433.89 34.65 193.02 1,377.18 1,266.54 -269.59 -78.84 2,619,207.72 1,455,234.85 3.74 279.74 MWD+SCC+SAG(1) 1,495.96 35.89 192.60 1,427.85 1,317.21 -304.54 -86.79 2,619,172.91 1,455,226.35 2.04 315.57 MWD+SCC+SAG(1) 1,558.62 37.52 192.32 1,478.09 1,367.45 -341.11 -94.86 2,619,136.47 1,455,217.69 2.62 353.01 MWD+SCC+SAG(1) 1,621.24 41.74 190.68 1,526.31 1,415.67 -380.24 -102.80 2,619,097.48 1,455,209.13 6.94 392.94 MWD+SCC+SAG(1) 1,653.10 44.26 189.55 1,549.61 1,438.97 -401.63 -106.61 2,619,076.15 1,455,204.97 8.27 414.66 MWD+SCC+SAG(1) 1,684.76 46.24 188.08 1,571.90 1,461.26 -423.85 -110.05 2,619,053.99 1,455,201.18 7.07 437.12 MWD+SCC+SAG(1) 1,718.58 46.87 189.29 1,595.15 1,484.51 -448.12 -113.76 2,619,029.79 1,455,197.08 3.20 461.65 MWD+SCC+SAG(1) 1,747.34 47.30 190.03 1,614.74 1,504.10 -468.89 -117.29 2,619,009.08 1,455,193.21 2.41 482.71 MWD+SCC+SAG(1) 1,810.50 48.65 190.54 1,657.02 1,546.38 -515.05 -125.67 2,618,963.06 1,455,184.10 2.22 529.62 MWD+SCC+SAG(1) 1,869.68 51.22 190.73 1,695.11 1,584.47 -559.56 -134.03 2,618,918.70 1,455,175.02 4.35 574.91 MWD+SCC+SAG(1) 1,936.77 52.31 191.13 1,736.63 1,625.99 -611.30 -144.03 2,618,867.13 1,455,164.20 1.69 627.60 MWD+SCC+SAG(1) 1,995.43 51.48 191.09 1,772.83 1,662.19 -656.59 -152.92 2,618,821.98 1,455,154.59 1.42 673.76 MWD+SCC+SAG(1) 2,059.55 50.23 191.10 1,813.30 1,702.66 -705.39 -162.49 2,618,773.35 1,455,144.24 1.95 723.49 MWD+SCC+SAG(1) 2,121.88 49.37 190.17 1,853.53 1,742.89 -752.18 -171.28 2,618,726.71 1,455,134.70 1.79 771.09 MWD+SCC+SAG(1) 2,185.18 48.61 191.25 1,895.07 1,784.43 -799.11 -180.15 2,618,679.93 1,455,125.07 1.76 818.86 MWD+SCC+SAG(1) 2,248.43 47.96 190.67 1,937.16 1,826.52 -845.46 -189.13 2,618,633.73 1,455,115.36 1.23 866.07 MWD+SCC+SAG(1) 2,310.69 47.27 190.13 1,979.13 1,868.49 -890.69 -197.43 2,618,588.64 1,455,106.33 1.28 912.05 MWD+SCC+SAG(1) 2,375.67 45.68 189.16 2,023.88 1,913.24 -937.14 -205.33 2,618,542.33 1,455,097.69 2.68 959.15 MWD+SCC+SAG(1) 2,438.98 43.64 188.39 2,068.91 1,958.27 -981.11 -212.12 2,618,498.47 1,455,090.19 3.33 1,003.61 MWD+SCC+SAG(1) 2,501.78 42.08 188.73 2,114.94 2,004.30 -1,023.35 -218.48 2,618,456.34 1,455,083.16 2.51 1,046.28 MWD+SCC+SAG(1) 2,563.56 39.80 189.00 2,161.61 2,050.97 -1,063.35 -224.72 2,618,416.45 1,455,076.28 3.70 1,086.73 MWD+SCC+SAG(1) 2,627.46 37.10 189.53 2,211.65 2,101.01 -1,102.56 -231.11 2,618,377.35 1,455,069.27 4.26 1,126.44 MWD+SCC+SAG(1) 2,690.89 35.80 189.16 2,262.67 2,152.03 -1,139.75 -237.23 2,618,340.27 1,455,062.55 2.08 1,164.11 MWD+SCC+SAG(1) 2,751.40 34.54 188.77 2,312.13 2,201.49 -1,174.18 -242.66 2,618,305.94 1,455,056.57 2.12 1,198.93 MWD+SCC+SAG(1) 2,815.13 33.29 188.68 2,365.01 2,254.37 -1,209.32 -248.06 2,618,270.88 1,455,050.61 1.96 1,234.46 MWD+SCC+SAG(1) 2,877.83 32.04 190.06 2,417.80 2,307.16 -1,242.71 -253.56 2,618,237.59 1,455,044.57 2.32 1,268.28 MWD+SCC+SAG(1) 2,941.54 30.41 190.45 2,472.28 2,361.64 -1,275.21 -259.44 2,618,205.19 1,455,038.18 2.58 1,301.30 MWD+SCC+SAG(1) 3,005.33 28.83 189.59 2,527.73 2,417.09 -1,306.25 -264.93 2,618,174.24 1,455,032.19 2.56 1,332.83 MWD+SCC+SAG(1) 7/6/2012 10:22:38AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report ,Company: ConocoPhillips(Alaska)Inc.-Expi Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River ND Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox; Site: Beluga River MD Reference: ' Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox;' Well: BRU 242-04 North Reference: True Wellbore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,068.83 27.01 189.36 2,583.84 2,473.20 -1,335.58 -269.82 2,618,145.00 1,455,026.82 2.87 1,362.54 MWD+SCC+SAG(1) 3,129.56 25.44 189.95 2,638.31 2,527.67 -1,362.04 -274.32 2,618,118.62 1,455,021.90 2.62 1,389.37 MWD+SCC+SAG(1) 3,191.47 23.51 190.13 2,694.66 2,584.02 -1,387.29 -278.79 2,618,093.44 1,455,017.03 3.12 1,415.01 MWD+SCC+SAG(1) 3,254.78 21.35 189.97 2,753.17 2,642.53 -1,411.07 -283.01 2,618,069.73 1,455,012.43 3.41 1,439.16 MWD+SCC+SAG(1) 3,352.40 18.54 190.95 2,844.93 2,734.29 -1,443.82 -289.03 2,618,037.09 1,455,005.88 2.90 1,472.46 MWD+SCC+SAG(2) 3,400.42 17.02 190.29 2,890.66 2,780.02 -1,458.23 -291.74 2,618,022.72 1,455,002.95 3.19 1,487.12 MWD+SCC+SAG(2) 3,463.87 13.80 187.04 2,951.82 2,841.18 -1,474.88 -294.32 2,618,006.11 1,455,000.09 5.25 1,503.96 MWD+SCC+SAG(2) 3,498.71 12.72 185.50 2,985.73 2,875.09 -1,482.82 -295.20 2,617,998.19 1,454,999.09 3.26 1,511.92 MWD+SCC+SAG(2) 3,525.12 12.57 185.74 3,011.50 2,900.86 -1,488.58 -295.77 2,617,992.44 1,454,998.43 0.60 1,517.67 MWD+SCC+SAG(2) 3,589.05 12.49 190.22 3,073.91 2,963.27 -1,502.30 -297.69 2,617,978.75 1,454,996.29 1.53 1,531.51 MWD+SCC+SAG(2) 3,652.03 12.72 190.70 3,135.37 3,024.73 -1,515.82 -300.19 2,617,965.28 1,454,993.58 0.40 1,545.26 MWD+SCC+SAG(2) 3,715.94 11.18 188.92 3,197.89 3,087.25 -1,528.85 -302.45 2,617,952.28 1,454,991.10 2.48 1,558.48 MWD+SCC+SAG(2) 3,778.73 10.68 192.05 3,259.54 3,148.90 -1,540.56 -304.61 2,617,940.62 1,454,988.76 1.24 1,570.38 MWD+SCC+SAG(2) 3,842.33 10.90 192.18 3,322.02 3,211.38 -1,552.20 -307.11 2,617,929.02 1,454,986.07 0.35 1,582.29 MWD+SCC+SAG(2) 3,902.78 10.78 192.10 3,381.39 3,270.75 -1,563.31 -309.50 2,617,917.94 1,454,983.50 0.20 1,593.66 MWD+SCC+SAG(2) 3,966.83 10.02 192.22 3,444.39 3,333.75 -1,574.62 -311.94 2,617,906.68 1,454,980.89 1.19 1,605.22 MWD+SCC+SAG(2) 4,030.43 10.17 191.99 3,507.00 3,396.36 -1,585.52 -314.27 2,617,895.82 1,454,978.37 0.24 1,616.36 MWD+SCC+SAG(2) 4,090.95 10.33 191.83 3,566.56 3,455.92 -1,596.05 -316.50 2,617,885.32 1,454,975.98 0.27 1,627.13 MWD+SCC+SAG(2) 4,154.77 10.29 191.10 3,629.35 3,518.71 -1,607.25 -318.77 2,617,874.16 1,454,973.53 0.21 1,638.55 MWD+SCC+SAG(2) 4,216.22 10.11 192.57 3,689.82 3,579.18 -1,617.90 -321.00 2,617,863.55 1,454,971.13 0.52 1,649.43 MWD+SCC+SAG(2) 4,281.50 10.03 190.05 3,754.10 3,643.46 -1,629.09 -323.24 2,617,852.40 1,454,968.72 0.69 1,660.84 MWD+SCC+SAG(2) 4,344.50 10.04 190.00 3,816.14 3,705.50 -1,639.90 -325.15 2,617,841.62 1,454,966.63 0.02 1,671.82 MWD+SCC+SAG(2) 4,408.55 9.79 189.42 3,879.23 3,768.59 -1,650.77 -327.01 2,617,830.79 1,454,964.60 0.42 1,682.84 MWD+SCC+SAG(2) 4,471.09 10.22 190.67 3,940.82 3,830.18 -1,661.47 -328.91 2,617,820.12 1,454,962.53 0.77 1,693.71 MWD+SCC+SAG(2) 4,535.21 10.40 191.37 4,003.90 3,893.26 -1,672.73 -331.10 2,617,808.89 1,454,960.15 0.34 1,705.18 MWD+SCC+SAG(2) 4,597.75 10.15 191.15 4,065.44 3,954.80 -1,683.67 -333.28 2,617,797.99 1,454,957.80 0.40 1,716.34 MWD+SCC+SAG(2) 4,660.16 10.29 191.41 4,126.86 4,016.22 -1,694.53 -335.44 2,617,787.17 1,454,955.46 0.24 1,727.41 MWD+SCC+SAG(2) 4,723.88 10.33 191.43 4,189.55 4,078.91 -1,705.71 -337.70 2,617,776.03 1,454,953.02 0.06 1,738.82 MWD+SCC+SAG(2) 4,787.12 10.25 192.05 4,251.77 4,141.13 -1,716.77 -340.00 2,617,765.01 1,454,950.55 0.22 1,750.11 MWD+SCC+SAG(2) 4,848.17 10.01 191.12 4,311.87 4,201.23 -1,727.29 -342.16 2,617,754.52 1,454,948.22 0.48 1,760.85 MWD+SCC+SAG(2) 4,910.58 9.92 190.24 4,373.34 4,262.70 -1,737.90 -344.16 2,617,743.95 1,454,946.05 0.28 1,771.65 MWD+SCC+SAG(2) 4,973.22 9.82 189.30 4,435.05 4,324.41 -1,748.48 -345.98 2,617,733.40 1,454,944.06 0.30 1,782.38 MWD+SCC+SAG(2) 5,037.12 10.07 192.15 4,497.99 4,387.35 -1,759.32 -348.04 2,617,722.59 1,454,941.83 0.86 1,793.41 MWD+SCC+SAG(2) 5,101.01 10.24 193.48 4,560.88 4,450.24 -1,770.30 -350.54 2,617,711.65 1,454,939.16 0.45 1,804.67 MWD+SCC+SAG(2) 5,162.48 10.35 192.34 4,621.36 4,510.72 -1,781.01 -352.99 2,617,700.98 1,454,936.53 0.38 1,815.65 MWD+SCC+SAG(2) 5,224.97 10.32 192.41 4,682.84 4,572.20 -1,791.96 -355.39 2,617,690.07 1,454,933.95 0.05 1,826.86 MWD+SCC+SAG(2) 5,286.63 10.15 191.97 4,743.52 4,632.88 -1,802.67 -357.71 2,617,679.41 1,454,931.47 0.30 1,837.81 MWD+SCC+SAG(2) 5,350.49 10.03 193.36 4,806.39 4,695.75 -1,813.58 -360.16 2,617,668.53 1,454,928.84 0.43 1,849.00 MWD+SCC+SAG(2) 5,413.09 9.96 193.38 4,868.04 4,757.40 -1,824.16 -362.67 2,617,658.00 1,454,926.16 0.11 1,859.85 MWD+SCC+SAG(2) 5,476.24 9.73 193.47 4,930.26 4,819.62 -1,834.66 -365.18 2,617,647.54 1,454,923.49 0.37 1,870.64 MWD+SCC+SAG(2) 7/6/2012 10:22:38AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Expl Local Co-ordinate Reference: Well BRU 242-04 Project: Beluga River TVD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox; Site: Beluga River MD Reference: Plan:242-04(18.5+92.14)@ 110.64ft(Arctic Fox; Well: BRU 242-04 North Reference: True Welibore: BRU 242-04 Survey Calculation Method: Minimum Curvature Design: BRU 242-04 Database: CPAI EDM Production Survey Map Map Vertical MD Inc ;Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,539.38 9.57 193.91 4,992.51 4,881.87 -1,844.94 -367.68 2,617,637.30 1,454,920.82 0.28 1,881.22 MWD+SCC+SAG(2) 5,602.35 10.08 191.87 5,054.55 4,943.91 -1,855.42 -370.08 2,617,626.87 1,454,918.26 0.98 1,891.96 MWD+SCC+SAG(2) 5,665.31 10.15 190.15 5,116.53 5,005.89 -1,866.27 -372.19 2,617,616.05 1,454,915.97 0.49 1,903.01 MWD+SCC+SAG(2) 5,728.58 10.02 190.04 5,178.83 5,068.19 -1,877.18 -374.13 2,617,605.18 1,454,913.86 0.21 1,914.09 MWD+SCC+SAG(2) 5,791.64 9.96 189.45 5,240.93 5,130.29 -1,887.96 -375.98 2,617,594.43 1,454,911.83 0.19 1,925.03 MWD+SCC+SAG(2) 5,853.67 9.88 189.15 5,302.03 5,191.39 -1,898.50 -377.71 2,617,583.91 1,454,909.94 0.15 1,935.71 MWD+SCC+SAG(2) 5,915.71 9.84 189.70 5,363.16 5,252.52 -1,908.98 -379.45 2,617,573.46 1,454,908.03 0.16 1,946.32 MWD+SCC+SAG(2) 5,980.28 9.76 189.45 5,426.79 5,316.15 -1,919.82 -381.27 2,617,562.65 1,454,906.03 0.14 1,957.31 MWD+SCC+SAG(2) 6,042.35 9.45 187.97 5,487.98 5,377.34 -1,930.06 -382.85 2,617,552.45 1,454,904.29 0.64 1,967.66 MWD+SCC+SAG(2) 6,105.54 9.16 187.79 5,550.34 5,439.70 -1,940.18 -384.25 2,617,542.35 1,454,902.73 0.46 1,977.86 MWD+SCC+SAG(2) 6,167.75 9.02 188.91 5,611.77 5,501.13 -1,949.90 -385.67 2,617,532.65 1,454,901.15 0.36 1,987.67 MWD+SCC+SAG(2) 6,231.97 9.55 190.39 5,675.15 5,564.51 -1,960.11 -387.41 2,617,522.47 1,454,899.24 0.91 1,998.03 MWD+SCC+SAG(2) 6,293.76 9.88 189.95 5,736.05 5,625.41 -1,970.38 -389.25 2,617,512.24 1,454,897.24 0.55 2,008.46 MWD+SCC+SAG(2) 6,356.77 10.37 189.96 5,798.08 5,687.44 -1,981.29 -391.17 2,617,501.36 1,454,895.15 0.78 2,019.53 MWD+SCC+SAG(2) 6,419.72 10.38 189.51 5,860.00 5,749.36 -1,992.46 -393.09 2,617,490.22 1,454,893.06 0.13 2,030.87 MWD+SCC+SAG(2) 6,482.50 10.37 189.45 5,921.76 5,811.12 -2,003.61 -394.95 2,617,479.10 1,454,891.01 0.02 2,042.17 MWD+SCC+SAG(2) 6,545.82 10.18 189.21 5,984.06 5,873.42 -2,014.76 -396.78 2,617,467.98 1,454,889.01 0.31 2,053.46 MWD+SCC+SAG(2) 6,608.40 9.93 188.86 6,045.68 5,935.04 -2,025.55 -398.50 2,617,457.22 1,454,887.12 0.41 2,064.37 MWD+SCC+SAG(2) 6,672.94 10.02 188.63 6,109.24 5,998.60 -2,036.60 -400.19 2,617,446.20 1,454,885.24 0.15 2,075.54 MWD+SCC+SAG(2) 6,734.96 9.85 187.08 6,170.34 6,059.70 -2,047.20 -401.66 2,617,435.63 1,454,883.61 0.51 2,086.23 MWD+SCC+SAG(2) 6,796.88 9.77 186.52 6,231.35 6,120.71 -2,057.67 -402.91 2,617,425.18 1,454,882.19 0.20 2,096.75 MWD+SCC+SAG(2) 6,860.77 9.76 186.88 6,294.31 6,183.67 -2,068.43 -404.17 2,617,414.44 1,454,880.75 0.10 2,107.55 MWD+SCC+SAG(2) 6,923.80 9.81 186.35 6,356.43 6,245.79 -2,079.07 -405.41 2,617,403.82 1,454,879.35 0.16 2,118.23 MWD+SCC+SAG(2) 6,987.55 9.79 186.26 6,419.25 6,308.61 -2,089.86 -406.60 2,617,393.05 1,454,877.99 0.04 2,129.04 MWD+SCC+SAG(2) 7,049.72 9.43 184.50 6,480.54 6,369.90 -2,100.19 -407.57 2,617,382.74 1,454,876.84 0.75 2,139.37 MWD+SCC+SAG(2) 7,113.24 9.28 182.87 6,543.22 6,432.58 -2,110.49 -408.24 2,617,372.45 1,454,876.01 0.48 2,149.60 MWD+SCC+SAG(2) 7,175.95 9.06 182.67 6,605.13 6,494.49 -2,120.48 -408.72 2,617,362.48 1,454,875.37 0.35 2,159.49 MWD+SCC+SAG(2) 7,221.00 9.06 182.67 6,649.62 6,538.98 -2,127.56 -409.05 2,617,355.40 1,454,874.93 0.00 2,166.51 PROJECTED to TD 7/6/2012 10:22:38AM Page 5 COMPASS 2003.16 Build 69 HALLIBURTON Sperry Drilling BRU 242-04 Days vs. Depth 0 , , Commenced 12.25"Surface —._ Hole Section 12 June 2012 19'MD/ 19'T VD —` Sperry SDL Arrives 1 June 2012 111 l on Location 1111111111111111111 111 1000 111 1I iii Conoc illi s P . ■■ aska,Inc. ,._11,...41 2000 --- -- •■■■■■■� ' ■ MUM 111111011111 III I. IN ■IM■ ■ ■■ Run&Land 7"Casing ■ Commenced 8.75"Production ■■-- 111111111111B Hole Section 3346'MD/2839 TVD --------- 3000 ■■■,.i•■■15. 11 June 2012 -c ■■ 111i1.111111111111■■1111 ■■ ►i■ E■■►7■■ E 1111111111111 11111111111111111 ■ 4000 TD 12.25"Production ■■'■■-■■.o , Hole Section 334'MD e 20 9 TVD ■■'■■�■■- ., I R __IIIIIIIIIIII■IIII..NI ■1111■■1111 ■1 II 1 .■..■■M M 5000 ■■ ■� 1■�■■1M■ n _ 11111 ■■■ rIIII I SI I I I I N NINE ■■ I■■ ■ ■ I■ _ ■■ IIIIIIIIIIIII ■M■ ■■ ■■■ 1111111111111 ■M■ ' ■■ - 6000 iniuiinhim IITD UlIllIl ■■� ,_ TD Production Section Ili' — Begin Wireline 7221'MD\6650'TVD Logging M 111 111 11■� 16 June 2012 1111111111 �� ■■ 7000 ■ �■ 21�■ Sperry Juully Released sed ■■ ■ ■ )_ �_ ■■ �■ . ._ II 111 8000 0 4 8 12 16 20 24 28 32 36 40 Rig Days