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Home My WebLink About213-049Nolan 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: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' 1 Gluyas, Gavin R (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, February 10, 2025 12:40 PM To:Eric Dickerman Subject:RE: PTD (213-049), Granite Point State 18742 17A (Anna-17A), Sundry #324-720 Eric, Hilcorp has approval to proceed with the plan below and then perforate assuming the results indicate that the plug is not leaking. Please send me the results of the GPT log and a plot of the tubing pressure over the course of the negative pressure test, as soon as they become available. It the GPT log indicates a fluid level above the cement, obtain approval from AOGCC before perforating. Otherwise, perforations can proceed according to sundry 324-720. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Monday, February 10, 2025 12:11 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: PTD (213-049), Granite Point State 18742 17A (Anna-17A), Sundry #324-720 Bryan, Per our discussion regarding Granite Point State 18742 17A (Anna-17A). Hilcorp will run a GPT looking for fluid level rise on the well before perforating. If a fluid level is seen, we will review with you prior to perforating. Recent notes:  The reservoir pressure below the CIBP at 6,800’ is estimated at 2,898 psi at 6,634’ tvd.  12/29/24: The well was stacked out with Nitrogen prior to setting the CIBP at 6,800’. A GPT logged the fluid level at 6,990’ prior to setting CIBP.  2/8/25: the tubing pressure was bleed oƯ to 500 psi to drawdown on the CIBP, and 27.9 gallons (28 ft) of cement was dumped on top of the CIBP at 6,800’. The plug was tested with 2,400 psi drawdown. 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. 2  Prior to perforating the tubing well be re-pressurized with N2 to prevent excessive underbalance. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 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. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 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): 13,670 N/A Casing Collapse Structural Conductor 520psi Surface 1,130psi Intermediate Production 3,330psi Liner 8,530psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 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 12/31/2024 12,915'3,512' 4-1/2" & 2-7/8" & 2-3/8" 11,107' TRSCSSSV 386' (MD) 386' (TVD) Perforation Depth MD (ft): 6,819 - 11,499 10,483' 7" 6,642 - 10,621 10,022'9-5/8" 10,483' 30" 20" 13-3/8" 610' 3,514' MD 2,110psi 2,730psi 610' 3,459' 610' 3,514' Length Size Proposed Pools: J-55 & L-80 TVD Burst 8,308' & 10,017 (LS) & (SS) 6,820psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 213-049 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20311-01-00 Hilcorp Alaska, LLC Granite Pt St 18742 17A AOGCC USE ONLY 11,220psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: Granite Point Hemlock Undefined Oil Middle Kenai Oil Granite Pt Gas Pool 11,297 6,800 6,624 1,989psi See schematic CO 76B No 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 12:15 pm, Dec 31, 2024 324-720 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.12.31 12:02:34 - 09'00' Dan Marlowe (1267) BJM 12/31/24 12/31/2024 10-404 RUSH Dump bail at least 25' of cement on top of plug at 6800' MD before perforating. Pressure test plug to 1700 psi either before or after dumping cement. SFD 1/1/2025MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.01.03 10:08:11 -09'00'01/03/25 RBDMS JSB 010925 Perf Add Well: Granite Point State 18742 17A (Anna-17A) Well Name:Granite Point State 18742 17A (Anna-17A) API Number:50-733-20311-01-00 Current Status:Offline Leg:Leg #2 (East corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:213-049 First Call Engineer:Casey Morse (907) 777-8322 Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Worst Expected BHP:2,500 psi @ 5,114’ TVD 9.4ppg mud from 2013 sidetrack Max. Potential Surface Pressure:1,989 psi Using 0.1 psi/ft Brief Well Summary Perforations added in the B-zones under sundry # 324-629 only found water. A plug was set to isolate the B- zone water, and we are requesting to move forward with perforating the A-zones from ~4090 – 5250’ MD. All proposed perforations are within the Granite Point Gas Pool per CO 76B. The A zones were drilled with mud weights of 9.4 ppg or less. The target zones range from TVD of 4010 – 5114’. x 9.4 ppg * 0.052 * 5114 ft TVD = 2500 psi x 0.1 psi/ft * (5114 – 4010 ft TVD) = 110 psi x 2500 – 110 = 2389 psi at the top perf x 2389 / 0.052 / 4010 = 11.46 ppg EMW The LOT at the surface casing shoe at 3443 ft TVD was 12.3 ppg EMW. The goal of this project is to add additional perforations in the Granite Point Gas Pool E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3000psi high 3. RIH and perforate Gas Sands from ±4,090’ - ±5,250’ MD (±4,010’ - ±5,114’ TVD) 4. RDMO EL Attachments: 1. Proposed Wellbore Schematic Updated by: JLL 12/31/24 Proposed Anna Platform Well No. AN-17A Completion Date: 12/12/2025 PTD: 213-049 API: 50-733-20311-01-00 Cement Details 13-3/8”17-1/2” hole: Cemented with 621bbls 13.4ppg Class G lead followed by 72bbls 15.2ppg tail . No losses. Saw returns to surface.ToC to surface. 9-5/8”12-1/4” Hole: Cemented with 450bbls 12.5ppg lead class cement, and 45bbls 15.8ppg tail cement. 119bbl losses throughout displacement.6/14/15 shows ToC at 3,125’ MD 4-1/2 X 9-5/8”Cemented with 285 bbls of 15.3 ppg. CBL from 12/16/24 shows TOC ~3,140’ MD. API # 50-733-20311-01 1 7” 9 5/8” 13 3/8” 20” 5 4 30” 3 9,403’ 6 S-Sleeve LWR 12,055’ 69° Top of Cement - 11,845’ 10 PBTD = 6,800’ MD 6,624 TVD) 4 A B 2 3 R R TOC @ 3,140’ CASING AND TUBING DETAIL SIZE (in) WT (lbs/ft) GRADE CONN ID (in) TOP (ft) BTM (ft) 30 94 X-55 - - Surf - 20 91.5 X-52 - 19.124 Surface 610 13-3/8 54.5, 61, 68, 72 K-55 & L-80 BTC 12.347 Surface 3,514 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 Tubing 4-1/2”12.75 J-55 EUE 8rd 3.958 Surface 8,308’ 2-3/8 (SS) 4.6 L-80 IBT SC 1.995 9,188’ 10,017’ 2-7/8 (LS) 6.4 L-80 EUE 2.441 9,215’ 9,223’ 2-7/8 (LS) 6.4 L-80 IBT SC 2.441 9,223’ 10,017’ Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status A Zone ±4,090 ±5,250 ±4,010’ ±5,114’ Future Proposed B-1 6,819 6,844 6,642’ 6,667’ 12/29/2024 Isolated (12/29/24) B-2 7,687 7,836 7,483’ 7,627’ 12/22/2024 Isolated (12/29/24) JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item Tubing Hanger 1 386’ 386’ 4-1/2” TRSCSSSV X-Profile 2 6,800’ 6,624’ CIBP set on 12/29/24 3 7,100’ 6,914’ CIBP set on 12/29/24 4 9,154’ 8,903’ Cement Retainer w/ 54 bbls 14 ppg cement on top A 10,017’ 9,662’ Kobe cavity 2 1/2"TOC @ 8,470’ Updated by: JLL 12/31/24 Proposed Anna Platform Well No. AN-17A Completion Date: 12/12/2025 PTD: 213-049 API: 50-733-20311-01-00 Isolated Jewelry Details Item Description ID (in) OD (in) Depth (ft) 3CIBP 11,875’ 4 Packer: 7" 26-32# Model "D" Permanent Pkr 3.250 5.810 11,900’ Concentric Packer Adapter 3.250 5.810 11,901’ Seal Bore Extension: 3.250'' X 5' 3.250 4.250 11,902’ Tbg Adapter:2-7/8'' EUE Box 2.810 4.990 11,906 ‘ 5 "R" - Landing Nipple 2.188 3.669 11,915’ 6 Sliding Sleeve 2 7/8'', "R" 2.188 3.190 12,055’ Pyrotechnic Delay Firing Head - 3.125 12,077’ Blank Safety Spacer: 4 1/2'' - 4.500 12,078‘ 6 SPF SDP TCP Assembly: 4.5'' Top Shot - 4.500 12,084’ 6 SPF SDP TCP Assembly: 4.5'' Btm Shot - 4.500 12,450’ Lower Firing Adapter: 4.5'' - 3.125 12,451’ Pyrotechnic Delay Firing Head - 3.125 12,453’ Isolated Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status C5B 9,241' 9,248' 8,980' 8,986' 7' 5 6/18/2015 Isolated (12/09/24) C5B 9,260' 9,279' 8,997' 9,014' 19' 5 6/18/2015 Isolated (12/09/24) C7A 9,541' 9,554' 9,253' 9,264' 13' 5 6/18/2015 Isolated (12/09/24) C7A 9,568' 9,580' 9,277' 9,288' 12' 5 6/18/2015 Isolated (12/09/24) C7C 9,652' 9,669' 9,352' 9,367' 17' 5 6/18/2015 Isolated (12/09/24) C7C 9,678' 9,704' 9,374' 9,397' 26' 5 6/18/2015 Isolated (12/09/24) C7E 9,758' 9,781' 9,444' 9,464' 23' 5 6/18/2015 Isolated (12/09/24) C8B 9,919' 9,969' 9,581' 9,623' 50' 5 6/18/2015 Isolated (12/09/24) C8C 10,013' 10,074' 9,659' 9,708' 61' 5 6/18/2015 Isolated (12/09/24) C9B 10,420' 10,433' 9,976' 9,985' 13' 5 6/18/2015 Isolated (12/09/24) C9C 10,580' 10,590' 10,091' 10,098' 10' 5 6/18/2015 Isolated (12/09/24) C9C 10,634' 10,648' 10,129' 10,139' 14' 5 6/18/2015 Isolated (12/09/24) C10 10,967' 10,972' 10,349' 10,352' 5' 5 6/18/2015 Isolated (12/09/24) C11 11,440' 11,455' 10,596' 10,603' 15' 5 6/18/2015 Isolated (12/09/24) C11 11,469' 11,499' 10,609' 10,621' 30' 5 6/18/2015 Isolated (12/09/24) Hemlock 11,969' 11,983' 11,224’ 11,237' 14' 6 6/14/2015 Isolated Hemlock 12,047' 12,067' 11,299’ 11,319’ 20' 6 6/14/2015 Isolated Hemlock 12,084' 12,450' 11,335’ 11,689’ 366' 6 6/14/2015 Isolated Hemlock 12,450' 12,453' 11,689’ 11,692’ 3' 12 6/14/2015 Isolated 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:Ryan Rupert Cc:Juanita Lovett; Dan Marlowe; Casey Morse; Eric Dickerman Subject:RE: Anna-17A CBL (PTD#213-049) Date:Wednesday, December 18, 2024 4:36:00 PM Ryan, Hilcorp has approval to proceed with perforations per the approved sundry. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, December 18, 2024 10:00 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Casey Morse <Casey.Morse@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Eric Dickerman <Eric.Dickerman@hilcorp.com> Subject: Anna-17A CBL (PTD#213-049) Bryan- Please see attached for the CBL acquired after the on-rig cement job for Anna-17A. Looks like just the confirmation we expected. Please advise if Hilcorp has approval to perforate per the sundry? Thanks, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GRANITE PT ST 18742 17A JBR 01/30/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 2 7/8" and 4 1/2" test joints, Light came unplugged on rig floor for H2S was reconnected and passed retest. Precharge Bottles = 1@900psi, 1@950psi, 8@1000psi, 6@1050psi, 3@1100 psi and 1@1150psi. Good Test. Test Results TEST DATA Rig Rep:R. Robson / E.MunozOperator:Hilcorp Alaska, LLC Operator Rep:D.Dunbar / E. Hooter Rig Owner/Rig No.:Team Snubbing TSI 101 PTD#:2130490 DATE:12/7/2024 Type Operation:WRKOV Annular: 250/3000Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopBDB241208114540 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 12 MASP: 2924 Sundry No: 324-629 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 10 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 0 NA #2 Rams 1 2 7/8x5 1/2 P #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1950 200 PSI Attained P30 Full Pressure Attained P114 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P6@1850 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector FP PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P14 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 99999 9 9 9 9 9 9 9 $QQD3ODWIRUP FP Light came unplugged on rig floor for H2S STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GRANITE PT ST 18742 17A JBR 01/29/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 This is the second half of this test. I only witnessed what I have selected. The Accumulator used for this test is the one typically used on the 404 and was in great working condition. Eveything functioned as normal. Remote panel functioned several times as well. Drawdown went well. Tested with 2-7/8" & 4-1/2"test joints. A body test was performed due to swapping ram operators after the initial part of this test. The dual VBR were tested with 2-7/8" on both sides. Tested the manual and hydraulic chokes, as well as the Kill and Choke HCR valves. No Issues with any thing. Test Results TEST DATA Rig Rep:Roland Robson/EnriqueOperator:Hilcorp Alaska, LLC Operator Rep:H. Soule/Ed Hooter Rig Owner/Rig No.:Team Snubbing TSI 101 PTD#:2130490 DATE:12/1/2024 Type Operation:WRKOV Annular: 250/3000Type Test:OTH Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopJDH241204213408 Inspector Josh Hunt Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 2924 Sundry No: 324-629 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NT Lower Kelly 0 NT Ball Type 2 P Inside BOP 1 NT FSV Misc 0 NA 10 NTNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 3/8" x 3 1/2 P #2 Rams 1 2 7/8" x 5.5" P #3 Rams 1 Blinds NT #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 5K" 5M NT HCR Valves 2 3 1/8 5K" 5M P Kill Line Valves 2 3 1/8 5K" 5M NT Check Valve 0 NA BOP Misc 0 NA System Pressure P2975 Pressure After Closure P1800 200 PSI Attained P36 Full Pressure Attained P137 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@1750 ACC Misc NA0 NT NTTrip Tank NT NTPit Level Indicators NT NTFlow Indicator NT NTMeth Gas Detector NT NTH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P7 #2 Rams P7 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9999 9 $QQD3ODWIRUP VHHDOVR,QVSHFWLRQ5SWERS*'& second half of this test only witnessed what I have selected Accumulator used for this test is the one typically used on the 404 body test was performed due to swapping ram operators STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________GRANITE PT ST 18742 17A JBR 01/29/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:5 2 3/8", 2 7/8" and 4.5" test joints used for testing. Gas detection lights were not in the view of the driller since there were none on the rig floor. Moved a set of strobes to the rig floor. The VBRs passed on test #6, but failed on test #7. No seals to rebuild them with on site so I didn't get to witness a pass on them. The response time of the annular was a fail. There were holes in the firewall that needed to be sealed. The remote control panel (drillers panel) was not on the rig floor and not functional. They may replace the entire accumulator system or increase the size of the hose running to the annular. Either way I did not witness a pass on this component either. In addition, I did not get to witness testing on the HCRs or the manual and hydralic chokes. Test Results TEST DATA Rig Rep:Tom Matthews/Roland Operator:Hilcorp Alaska, LLC Operator Rep:Darcy Dunbar/Ed Hooter Rig Owner/Rig No.:Team Snubbing TSI 101 PTD#:2130490 DATE:11/28/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopGDC241122135606 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 15 MASP: 2924 Sundry No: 324-629 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 10 PNo. Valves 1 NTManual Chokes 1 NTHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 3000 P #1 Rams 1 2 3/8" Solid P #2 Rams 1 2 7/8"x5.5" V F #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"" 5000 P HCR Valves 2 3 1/8"" 5000 NT Kill Line Valves 2 3 1/8"" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3100 Pressure After Closure P1650 200 PSI Attained P29 Full Pressure Attained P167 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2050 ACC Misc F2 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 1 FPMS Misc Inside Reel Valves 0 NA Annular Preventer F31 #1 Rams P8 #2 Rams P8 #3 Rams P8 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9999 9 99 9 9 9 9 99 9 9 9 $QQD3ODWIRUP 2 Rams 2 7/8"x5.5" V F 1 FPMS Misc ACC Misc 2 F Annular Preventer 31 F Gas detection lights were not in the view of the driller VBRs failed on test #7 response time of the annular was a fail.holes in the firewall remote control panel (drillers panel) was not on the rig floor not functional replace the entire accumulator system P.I. Supv Comm: Rig Coil Tubing Unit? No Rig Contractor Rig Representative Operator Operator Representative Well Permit to Drill # 213-049 Sundry Approval # 324-629 Operation Inspection Location Working Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure P P Flow Rate Sensor NA Operating Pressure P P Mud Gas Separator P Fluid Level/Condition P P Degasser NA Pressure Gauges P P Separator Bypass P Sufficient Valves P P Gas Detectors FP Regulator Bypass P P Alarms Separate/Distinct P Actuators (4-way valves) P P Choke/Kill Line Connections P Blind Ram Handle Cover P P Reserve Pits P Control Panel, Driller F P Trip Tank NA Control Panel, Remote P P Firewall F P 2 or More Pumps P P Kelly or TD Valves NA Independent Power Supply P P Floor Safety Valves P N2 Backup P P Driller's Console P Condition of Equipment P PFlow MonitorNA Flow Rate Indicator NA Pit Level Indicators FP Valves P PPE P Gauges P Remote Hydraulic Choke P Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P Housekeeping P Hydraulic Control Panel P Targeted Turns P Well Control Plan P Kill Sheet Current NA Bypass Line P FAILURES:4 CORRECT BY: COMMENTS Holes in firewall of Accumulator shack need to be sealed. Not fixed before I left location. Gas detection strobes not on rig floor within the sight of the driller. A pair of strobes were moved to the rig floor. Pit level indicators were not hooked up and functional. They were hooked up and tested good. Drillers control for the accumulator was not on the rig floor or functional. Not fixed before I left location. CHOKE MANIFOLD Anna Platform MUD SYSTEM Granite Pt. St. 18742 17A Workover CLOSING UNIT ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT HCR Valve(s) Manual Valves Annular Preventer Working Pressure, BOP Stack Stack Anchored Choke Line Kill Line Targeted Turns Pipe Rams Blind Rams Tom Matthews Darcy Dunbar Locking Devices, Rams BOP STACK Guy Cook 11/27/2024INSPECT DATE AOGCC INSPECTOR Before moving forward with well work. TS1 101 Team Snubbing Int'l Hilcorp Alaska LLC MISCELLANEOUS Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines RIG FLOOR 2024-1127_Rig_TSI101_GranitePt_Anna-17A_gc rev. 4-19-2023 9 9 9 9 9 9 9 -5HJJ Holes in firewall of Accumulator shack Gas detection strobes Pit level indicators Drillers control for the accumulator 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:Ryan Rupert Cc:Dan Marlowe; Juanita Lovett; Dewhurst, Andrew D (OGC) Subject:RE: Granite Point State 18742 17A (Anna-17A)_PTD#213-049 Date:Tuesday, November 26, 2024 5:25:00 PM Attachments:V4_Anna-17A_AOGCC Wellwork Procedure(11-26-24) - bjm.pdf An-17A Proposed 2024-11-26.pdf Ryan, Hilcorp has approval to make the changes as written in the attached update and proposed wellbore diagram, with one exception. Continue squeezing below retainer as long as injection rate is 0.5 bpm or greater at max squeeze pressure. Be sure to include enough cement retarder to pump away the entire volume at that rate. I made a note in the attached procedure accordingly. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Tuesday, November 26, 2024 4:57 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: Granite Point State 18742 17A (Anna-17A)_PTD#213-049 Bryan- Please see attached for change of procedure on Anna-17A HWO currently in progress. The changes modify and clarify the cementing operations, and modify the proposed perfs downward slightly. An updated proposed schematic is attached. Please let us know if Hilcorp has approval to proceed with the amended path forward below. Thank you. Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) 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. Updated by: JLL 11/26/24 PROPOSED Anna Platform Well No. AN-17A Completion Date: FUTURE PTD: 213-049 API: 50-733-20311-01-00 Cement Details 13-3/8”17-1/2” hole: Cemented with 621bbls 13.4ppg Class G lead followed by 72bbls 15.2ppg tail . No losses. Saw returns to surface.ToC to surface. 9-5/8”12-1/4” Hole: Cemented with 450bbls 12.5ppg lead class cement, and 45bbls 15.8ppg tail cement. 119bbl losses throughout displacement.6/14/15 shows ToC at 3,125’ MD 4-1/2 X 9-5/8”Target TOC ±3,000’ MD API # 50-733-20311-01 1 7” 9 5/8” 13 3/8” 20” 5 4 30” 3 9,403’ 6 S-Sleeve LWR 12,055’ 69° Top of Cement - 11,845’ 10 PBTD =±9,000’ MD (±8,754’ TVD) 2 A B R R CASING AND TUBING DETAIL SIZE (in) WT (lbs/ft) GRADE CONN ID (in) TOP (ft) BTM (ft) 30 94 X-55 - - Surf - 20 91.5 X-52 - 19.124 Surface 610 13-3/8 54.5, 61, 68, 72 K-55 & L-80 BTC 12.347 Surface 3,514 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 Tubing 4-1/2” Surf ±9,050’ 2-3/8 (SS) 4.6 L-80 IBT SC 1.995 ±9,197’10,017’ 2-7/8 (LS) 6.4 L-80 EUE 2.441 ±9,200’9,223’ 2-7/8 (LS) 6.4 L-80 IBT SC 2.441 9,223’ 10,017’ Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status ±6,000’ ±7,900’ ±5,837’ ±7,687’ Future Proposed JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item Tubing Hanger 1 ±350’ ±350’ SSSV 2 ±9,150’ ±8,896’ Cement Retainer A ±9,200’ ±8,942’XO 2 7/8" 8Rnd EUE X 2 7/8" IBT SCC 10,015’ 9,661’ XO 2 7/8" IBT SCC X 2 7/8" EUE 10,017’ 9,662’ Kobe cavity 2 1/2" 10,023’ 9,667’ "R"- Landing Nipple 10,056’ 9,694’ Ratcheting Mule Shoe B ±9,197’ ±8,939’XO 2 7/8" 8rnd EUE X 2 3/8" IBT SCC 10,017’ 9,662’ XO 2 3/8" IBT SCC X 1.25 NPT Updated by: JLL 11/26/24 PROPOSED Anna Platform Well No. AN-17A Completion Date: FUTURE PTD: 213-049 API: 50-733-20311-01-00 Isolated Jewelry Details Item Description ID (in) OD (in) Depth (ft) 3 CIBP 11,875’ 4 Packer: 7" 26-32# Model "D" Permanent Pkr 3.250 5.810 11,900’ Concentric Packer Adapter 3.250 5.810 11,901’ Seal Bore Extension: 3.250'' X 5' 3.250 4.250 11,902’ Tbg Adapter:2-7/8'' EUE Box 2.810 4.990 11,906 ‘ 5 "R" - Landing Nipple 2.188 3.669 11,915’ 6 Sliding Sleeve 2 7/8'', "R" 2.188 3.190 12,055’ Pyrotechnic Delay Firing Head - 3.125 12,077’ Blank Safety Spacer: 4 1/2'' - 4.500 12,078‘ 6 SPF SDP TCP Assembly: 4.5'' Top Shot - 4.500 12,084’ 6 SPF SDP TCP Assembly: 4.5'' Btm Shot - 4.500 12,450’ Lower Firing Adapter: 4.5'' - 3.125 12,451’ Pyrotechnic Delay Firing Head - 3.125 12,453’ Isolated Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status C5B 9,241' 9,248' 8,980' 8,986' 7' 5 6/18/2015 Isolated (Future) C5B 9,260' 9,279' 8,997' 9,014' 19' 5 6/18/2015 Isolated (Future) C7A 9,541' 9,554' 9,253' 9,264' 13' 5 6/18/2015 Isolated (Future) C7A 9,568' 9,580' 9,277' 9,288' 12' 5 6/18/2015 Isolated (Future) C7C 9,652' 9,669' 9,352' 9,367' 17' 5 6/18/2015 Isolated (Future) C7C 9,678' 9,704' 9,374' 9,397' 26' 5 6/18/2015 Isolated (Future) C7E 9,758' 9,781' 9,444' 9,464' 23' 5 6/18/2015 Isolated (Future) C8B 9,919' 9,969' 9,581' 9,623' 50' 5 6/18/2015 Isolated (Future) C8C 10,013' 10,074' 9,659' 9,708' 61' 5 6/18/2015 Isolated (Future) C9B 10,420' 10,433' 9,976' 9,985' 13' 5 6/18/2015 Isolated (Future) C9C 10,580' 10,590' 10,091' 10,098' 10' 5 6/18/2015 Isolated (Future) C9C 10,634' 10,648' 10,129' 10,139' 14' 5 6/18/2015 Isolated (Future) C10 10,967' 10,972' 10,349' 10,352' 5' 5 6/18/2015 Isolated (Future) C11 11,440' 11,455' 10,596' 10,603' 15' 5 6/18/2015 Isolated (Future) C11 11,469' 11,499' 10,609' 10,621' 30' 5 6/18/2015 Isolated (Future) Hemlock 11,969' 11,983' 11,224’ 11,237' 14' 6 6/14/2015 Isolated Hemlock 12,047' 12,067' 11,299’ 11,319’ 20' 6 6/14/2015 Isolated Hemlock 12,084' 12,450' 11,335’ 11,689’ 366' 6 6/14/2015 Isolated Hemlock 12,450' 12,453' 11,689’ 11,692’ 3' 12 6/14/2015 Isolated Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) WellName:GranitePointState 1874217A(AnnaͲ17A) APINumber:50Ͳ733Ͳ20311Ͳ01Ͳ00 CurrentStatus:OfflineJPOilProducerLeg:Leg#2(Eastcorner) RegulatoryContact:JuanitaLovett(8332)PermittoDrillNumber:213Ͳ049 FirstCallEngineer:RyanRupert(907)301Ͳ1736(c) SecondCallEngineer:DanMarlowe(907)398Ͳ9904(c) WorstExpectedBHP: 3,758psi@7,687’TVD 9.4ppgmudfrom2013sidetrack Max.PotentialSurfacePressure:2924psi2990psi Using0.1psi/ft BriefWellSummary AnnaͲ17Awassidetrackedtoitscurrentlocationin2013.New9Ͳ5/8”casingwasrunbacktosurfaceand cemented.ThisprovidesoneofthefewwellsinGranitePointthathascementwellupholeabovetheoilpools. ThewellhasbeenSIsince2018duetolowinflowandhighwatercut.ThesefactorsmakeAnnaͲ17Aagood candidatetorecompleteupholeandtargetgasproductionfromtheGranitePointGasPool. Thegoalofthisprojectistoabandontheexistingoilcompletion,andrecompleteforupholegasproduction Updatesinredfrom11/26/24revision Pertinentwellboreinformation: x MaxinclinationabovePBTD:70degreesbelow11,600’MD x 2013sidetrack o Existing9Ͳ5/8”wascut/pullfrom~100’below13Ͳ3/8”shoe o Cementpluglaidin,andkickedoffforsidetrack o New9Ͳ5/8”casingand7”linerran o InitialcompletiontestedGranitePointHemlockOilPool(wet) x 2015RecompletetoTyonekoilsands(MiddleKenaiOilPool) o Set7”CIBPat11,875’MDanddumpbail30’ofcementtoP&AtheGranitePointHemlockOil Pool o CBLof9Ͳ5/8”casingshowsToCat3,125’MD o PTofcasingto1500psiGOOD(15mins) o TCPMiddleKenaiOilPoolsandsin7”and9Ͳ5/8”casing o RancurrentdualJPcompletion x 7/30/15:passedNoFlowTest x 8/15/15:Lastdriftofshortstring.1.75”bailerto10,017’MD.1.85”gaugeringcan’tpass9458’SLMD x 12/7/15:Foundscaleintubingtail,andpunchedaboveitfrom10,030–10,036’toreestablish communication x 11/2/16:lasttimestandingvalvewaspulled.Hadtobailscale Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) PoolsinAnnaͲ17A: x TopGranitePointGasPool:3,272’MD(3,230’TVD) x TopGranitePointMiddleKenaiOilPool:8610’MD(8,378’TVD) x TopGranitePointHemlockOilPool:11,956MD(10,791’TVD) o AlreadyP&A’dviaCIBPandcementat11,875’MD(10,763’TVD) Pressures: x OpenGranitePointMiddleKenaiOilPoolperfs(CͲsands) o 2015RWOhad6.8ppgdieselinwellbeforeshootingtheCsands o Wellwentonvacafterperforating o Nonearbyinjection. o ReservoirPtoday<6.8ppg x ProposedGranitePointGasPoolperfs o Baseat7,687’7,521’TVD o Wasdrilledin2013withmudweightsat9.4PPGandless o 9.4ppg*0.052*7,687ftTVD=3,758psi o 0.1psi/ft*7,687ftTVD=768psi o MPSPfromGasSands=3758–768=2990psi x 1977D&Cobtaineda12.3ppgLOTat13Ͳ3/8”shoe(3,459’TVD) x TheproposedGasperfsinAnnaͲ17Aarefrom5,837’Ͳ7,687’TVD o 9.4ppg*0.052*7,687ftTVD=3,758psi o 0.1psi/ft*(7,687ftTVD–5,837ftTVD)=185psi o 3,758psi–185psi=3572psi(at5,837ftTVD) o 3,572psi/0.052/5,837’TVD=11.8ppg x Wecanperfupto6,000’MD(5,837’TVD)inAnnaͲ17Aandstaywellunderthe12.3ppgFIT 9Ͳ5/8”Cement(2013): x 12Ͳ1/4”holedrilledoffacementplugat13Ͳ3/8”casingshoe x Stringwascementedwith450bblsof12.5ppgleadcementfollowedby45bblsof15.8ppgtailcement x 119bblslossesthroughoutjob x 6/14/15CBLshowsToCat3,125’MD. HWOConditions x Operationsshallbe24hrscontinuous x Traditionalwellcontrolapproachwillbeimplemented x FilteredInletwater(FIW)willbeusedaskillweightfluid(8.4ppgorgreater) x KWFwillbeabarrieratalltimesduringHWOoperations x Snubbingoperationswillonlybeperformedattheveryendofthejob(seebelow) x TeamSnubbing’sBOPstackwillbeusedforthisoperation(seeattachment) Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) HWOProcedure: 1. MIRUTeamSnubbingHydraulicWorkover(HWO)Unit(SnubbingInternational,Alberta,Canada) 2. Circulate/Bullheadkillwell: a. Workoverfluidwillbefreshwater(8.33ppg)orheavier b. EnsureanywellborefluidsarefullydisplacedwithKWFviacirculationandbullheading c. WBV=722bbls i. Longstring:58bbls ii. Shortstring:56bbls iii. IAabovetubingtail:554 iv. 7”Linerbelowtubingtail:54bbls 3. SetBPVs/TWCs,NDtree,NUBOP a. NotifyAOGCC48hoursinadvanceforwitness b. Testto250psiLow/3,000psiHigh/2,500psiAnnular c. BOP’swillbeclosedasneededtocirculatethewell d. Testtocoverexisting2Ͳ7/8”and2Ͳ3/8”tubing,plusnew4Ͳ1/2”tubing e. Planningtopullonestringatatime f. Iftubingstringswillonlypulltogether,wewillneedtoinstallandtestadualboreinsertfirst 4. PullTWCs/BPVs 5. Cutshortstring a. RUELtoshortstring b. RIHandcutjustaboveKobeblockat10,017’MD2Ͳ7/8”x2Ͳ3/8”Crossoverat9,197’MD 6. Moveovertolongstringandcutat±9,200’MD 7. RDEL 8. UnseatShortstringandPOOHwith2Ͳ7/8”x2Ͳ3/8”tubing 9. UnseatLongstringandPOOHwith2Ͳ7/8”tubing,Kobeblock,andtailpipe 10. RIHandset9Ͳ5/8”plugat±9,225’MD(8,936’TVD)toabandontheGranitePointMiddleKenaiOilPool 11. Afterset,tagplugwithELorworkstringtoconfirmdepth Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) 12. PUpipeandRIHwith9Ͳ5/8”cementretainer(mayuse2Ͳ7/8”workstringor4Ͳ1/2”completiontubing. TBD) 13. Set9Ͳ5/8”cementretainerat±9,150’MD(8,896’TVD):91’abovetopperf ±8,750’MD(8,514’TVD):491’abovetopperf 14. Downsqueeze100bblsofcementtoabandontheGranitePointMiddleKenaiOilPool a. 9Ͳ5/8”volumebelowretainer=18bbls b. 7”volumedownto100’belowbottomperf=82bbls c. Attempttopumpkeepingsurfacepressuresbelow1000psi d. Ifunabletopumpatleast2.0bpmwhilestayingbelowmaxpressure,oktoincreasemax surfacepressureto2000psiandfracawaytheremainderofthejob i. 9Ͳ5/8”47#PͲ110burstrating@9440psi*70%=6608psi ii. 7”29#PͲ110burstrating@11,220psi*70%=7854psi iii. Deepest9Ͳ5/8”casingat9403’MD/9128’TVD iv. 15.8ppgcement@9128’TVD=7500psihydrostaticpressure v. 8.4ppgoverburdenoutside9Ͳ5/8”casingat9128’TVD=3987psi vi. Nethydrostaticforceexertedbycolumnofcement:7263–3987=3513psi vii. 70%burst@6608psi–3513psinethydrostatic=3095psiallowableappliedpressure viii. 12/12/13:FITpassedto15.0ppgat9Ͳ5/8"casingshoeat10,483'MD/10,025'TVD ix. Ifpumpratesfallbelow1.0bpmatmaxpressureduringdownsqueeze,unstingandlay inremainingvolumeontopofretainer.Ifpumpratefallsbelow0.5bpm,unstingand layinremainingcementontopofretainer…Ͳbjm 15. Unstingfromcementretainerandlayinanyremainingcement5.5bblsontoptargetingToC=8600’ MD(8,369’TVD) a. Possiblefor0bblscementontopofretainerifsqueezegoeswell,andthat’spermissible b. CirculateoutexcesscementasnecessarytokeepToCatorbelow8000’MD c. Volumein9Ͳ5/8”from8600’MDtoretainerat8750’MD=5.5bbls d. ThisbringsToCtotopGranitePointMiddleKenaiOilPool(8610’MD/8378’TVD) 16. MITto2250psi(charted)down9Ͳ5/8”casingagainstcement+retainer a. Provesplugandcasingintegrity b. Providestatewith48hrwitnessnotification c. 8896TVD*0.25=2224psi 17. MU4Ͳ1/2”completion a. SSSVat±350’MD b. Targetbottomofcompletionat9050’MD(8802’TVD)(±100’aboveexistingToC)at±8500’MD /8272’TVD. c. Adjustbottomofcompletionupwardasnecessarytoaccommodatecementontopofretainer (ifany) d. Bottomcompletiontobenoshallowerthan7,950’MD(7,735’TVD) 18. RIHandlandcompletion 19. Circulate325bblscementinto4Ͳ1/2”x9Ͳ5/8”annulus a. TargetToCat±3000’MD(2975’TVD) b. 4Ͳ1/2”x9Ͳ5/8”annulusvolumefrom3000’–9050’=325bbls c. ThisbringsToCabovethesurfacecasingshoe,and~250’abovethetopGranitePointGasPool d. Adjustcementvolumeasnecessarydependingonfinalbottomofcompletion 20. NDBOP,NUtreeandtest Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) 21. WoC Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) PostͲRigProcedureandSnubbingOperations 1. ObtainCBL.SubmitresultstoAOGCC 2. MITͲIAto2250psi(charted) 3. Snubbingprep a. Reviewsundry b. ReviewCOA’s c. ReviewIRP15,specificallyallshallandmuststatements 4. RUandtestsnubbingstack(perattachment) a. NotifyAOGCC48hoursinadvanceforwitness b. Testto250psiLow/3,000psiHigh c. SubbingstackwillberiggeduptothetopoftheproductiontreeafterHWOBOPEisremoved d. Snubbingstackwillonlybeaddedforthefinaloperation 5. PU2Ͳ3/8”jointedpipeworkstring a. Wellwillbestillloadedwithfluid,andisolatedfromformation b. NosnubbingoperationsneededforRIH c. Ensureworkstringhasafloatinstalledforforwardcirculationonly d. Test/chartfloatto3400psiperIRP15 i. 2600psiN2pressure ii. 2600psi*1.3=3380psi 6. RIHwith2Ͳ3/8”jointedworkstringandonceonbottomblowwelldrywithN2viaforwardcirculation a. PumpN2downworkstring b. Takereturnsout4Ͳ1/2”x2Ͳ3/8”annulus c. Ensurereturnsaretakendirectlytoanopentoptank,andnitrogenisventedappropriately d. Returnsarenottobetaken‘inside’toamudsystem e. Mud/pumpingsystemwillbeRDMObythisstep 7. Trap2600psinitrogenpressureonwellbore(orlessperOE) 8. SnubOOHwith2Ͳ3/8”workstring 9. DemobHWO/snubbingunitandcrew EͲLinePerfprocedure 1. MIRUEͲlineandpressurecontrolequipment 2. PTlubricatorto250psilow/3000psihigh 3. EnsureCBLapprovalfromAOGCCbeforeperforating 4. RIHandperforateGasSandsfrom±6,000’Ͳ±7,900’MD(±5,837’Ͳ±7,687’TVD)±5,653’–±7,730’MD (±5,500’Ͳ7,521’TVD)perRE/Geo 5. RDMOEL Note:Hilcorpwilllikelywanttoperfandproduceabovetherequestedtopperffromabove.Beforeperf’ing above±6,000’MD(±5,837’TVD)Hilcorpmustreviewcurrentwellstatus/perfs/plugs/pressureswiththe agencyandobtainadditionalapproval.FYI Version#4(11/26/24)RecompleteforGasHWO Well:GranitePointState1874217A(AnnaͲ17A) CONTINGENCYplug:(ifanyzonemakesunwantedsolidsorwater) 1. RUnitrogentotubingandPTlinesto3000psi(orhigherifneeded) 2. Pressureupontubinganddisplacewaterbackintoformation 3. MIRUEͲlineandpressurecontrolequipment 4. PTlubricatorto250psilow/3000psihigh 5. Set4Ͳ1/2”isolationplugorpatchperOE 6. RDMONitrogenandEL CONTINGENCYCTCleanout:(ifanyzonebringsinexcessivefillandneedstobecleanedout) 1. MIRUCoiledTubingandpressurecontrolequipment 2. PTlubricatorto250psilow/3000psihigh 3. MUFCOBHA 4. RIHandcleanouttoPBTDorasdeepaspractical a. Workingfluidwillbewater(8.33ppgorgreater) b. TakereturnstosurfaceuptheCTxtubingannulus c. Addfoamandnitrogenasnecessarytocarrysolidstosurface d. CanuseGLtoassistwithholecleaning 5. Oncecleanoutiscompleted,blowwelldownwithnitrogen 6. RDMOCT Attachments: 1. CurrentWellboreSchematic 2. ProposedWellboreSchematic 3. CurrentWellheadDiagram 4. ProposedWellheadDiagram 5. HWOBOPDrawing(TSI) 6. SnubbingBOPdiagram(TSI) 7. HWOFluid/FlowDiagrams(TSI) 8. IRP15compliancematrix 9. Snubbingstackstabilizationdiagram(TSI) 10. FoxCTBOPDiagram 11. OffshoreNitrogenprocedure 12. RWOSundryChangeForm 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 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): 13,670 N/A Casing Collapse Structural Conductor 520psi Surface 1,130psi Intermediate Production 3,330psi Liner 8,530psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 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 Other: HWO / N2 Operations Granite Point Hemlock Undefined Oil Middle Kenai Oil Granite Pt Gas Pool 11,297 11,845 10,752 2,924psi 11,875 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 11,220psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 213-049 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20311-01-00 Hilcorp Alaska, LLC Granite Pt St 18742 17A Length Size Proposed Pools: L-80 TVD Burst 10,017 (LS) & (SS) 6,820psi MD 2,110psi 2,730psi 610' 3,459' 610' 3,514' 30" 20" 13-3/8" 610' 3,514' 9,241 - 11,499 10,483' 7" 8,980 - 10,621 10,022'9-5/8" CO 76B 11/18/2024 12,915'3,512' 2-7/8" & 2-3/8" 11,107' Model D Packer & N/A 11,900 (MD) 11,157 (TVD) & N/A 10,483' Perforation Depth MD (ft): No 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 9:46 am, Nov 04, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.11.04 08:16:36 - 09'00' Dan Marlowe (1267) 324-629 Perforate New Pool DSR-11/20/24 X BJM 11/20/24 BOP test to 3000 psi, annular test to 2500 psi. Provide 48 hrs notice for opportunity to witness cement plug pressure test to 2250 psi. 10-404 X Within 30 days of production, after final perf was added, MITIA to 2250 psi to test integrity of IA cement above the top perf. SFD 11/20/2024 Plug Perforations *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.21 10:29:27 -08'00'11/21/24 RBDMS JSB 112624 Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) Well Name:Granite Point State 18742 17A (Anna-17A) API Number:50-733-20311-01-00 Current Status:Offline JP Oil Producer Leg:Leg #2 (East corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:213-049 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Worst Expected BHP:3,677 psi @ 7,521’ TVD 9.4ppg mud from 2013 sidetrack Max. Potential Surface Pressure: 2924 psi Using 0.1 psi/ft Brief Well Summary Anna-17A was sidetracked to its current location in 2013. New 9-5/8” casing was run back to surface and cemented. This provides one of the few wells in Granite Point that has cement well uphole above the oil pools. The well has been SI since 2018 due to low inflow and high water cut. These factors make Anna-17A a good candidate to recomplete uphole and target gas production from the Granite Point gas Pool. The goal of this project is to abandon the existing oil completion, and recomplete for uphole gas production Pertinent wellbore information: x Max inclination above PBTD: 70 degrees below 11,600’ MD x 2013 sidetrack o Existing 9-5/8” was cut/pull from ~100’ below 13-3/8” shoe o Cement plug laid in, and kicked off for sidetrack o New 9-5/8” casing and 7” liner ran o Initial completion tested Granite Point Hemlock Oil Pool (wet) x 2015 Recomplete to Tyonek oil sands (Middle Kenai Oil Pool) o Set 7” CIBP at 11,875’ MD and dump bail 30’ of cement to P&A the Granite Point Hemlock Oil Pool o CBL of 9-5/8” casing shows ToC at 3,125’ MD o PT of casing to 1500psi GOOD (15 mins) o TCP Middle Kenai Oil Pool sands in 7” and 9-5/8” casing o Ran current dual JP completion x 7/30/15: passed No Flow Test x 8/15/15: Last drift of short string. 1.75” bailer to 10,017’ MD.1.85” gauge ring can’t pass 9458’ SLMD x 12/7/15: Found scale in tubing tail, and punched above it from 10,030 – 10,036’ to reestablish communication x 11/2/16: last time standing valve was pulled. Had to bail scale Superseded Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) Pools in Anna-17A: x Top Granite Point Gas Pool: 3,272’ MD (3,230’ TVD) x Top Granite Point Middle Kenai Oil Pool: 8610’ MD (8,378’ TVD) x Top Granite Point Hemlock Oil Pool: 11,956 MD (10,791’ TVD) o Already P&A’d via CIBP and cement at 11,875’ MD (10,763’ TVD) Pressures: x Open Granite Point Middle Kenai Oil Pool perfs (C-sands) o 2015 RWO had 6.8ppg diesel in well before shooting the C sands o Well went on vac after perforating o No nearby injection. o Reservoir P today < 6.8ppg x Proposed Granite Point Gas pool sands o Base at 7,521’ TVD o Was drilled in 2013 with mud weights at 9.4PPG and less o 9.4 ppg * 0.052 * 7,521 ft TVD = 3,677 psi o 0.1 psi/ft * 7,521 ft TVD = 752 psi o MPSP from Gas Sands = 3677 – 752 = 2924psi x 1977 D&C obtained a 12.3ppg LOT at 13-3/8” shoe (3,459’ TVD) x The proposed Gas perfs in Anna-17A are from 5,550’ - 7,521’ TVD o 9.4 ppg * 0.052 * 7,521 ft TVD = 3,677 psi o 0.1 psi/ft * (7,521 ft TVD – 5,550 ft TVD) = 197 psi o 3,677 psi – 197 psi = 3480 psi (at 5,500 ft TVD) o 3480 psi / 0.052 / 5,500’ TVD = 12.1ppg x We can perf up to 5,653’ MD (5,500’ TVD) in Anna-17A and stay under the 12.3ppg FIT 9-5/8” Cement (2013): x 12-1/4” hole drilled off a cement plug at 13-3/8” casing shoe x String was cemented with 450bbls of 12.5ppg lead cement followed by 45bbls of 15.8ppg tail cement x 119bbls losses throughout job x 6/14/15 CBL shows ToC at 3,125’ MD. HWO Conditions x Operations shall be 24hrs continuous x Traditional well control approach will be implemented x Filtered Inlet water (FIW) will be used as kill weight fluid (8.4ppg or greater) x KWF will be a barrier at all times during HWO operations x Snubbing operations will only be performed at the very end of the job (see below) x Team Snubbing’s BOP stack will be used for this operation (see attachment) Superseded Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) HWO Procedure: 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit (Snubbing International, Alberta, Canada) 2. Circulate / Bullhead kill well: a. Work over fluid will be fresh water (8.33ppg) or heavier b. Ensure any wellbore fluids are fully displaced with KWF via circulation and bullheading c. WBV = 722 bbls i. Long string: 58 bbls ii. Short string: 56 bbls iii. IA above tubing tail: 554 iv. 7” Liner below tubing tail: 54 bbls 3. Set BPVs / TWCs, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Test to cover existing 2-7/8” and 2-3/8” tubing, plus new 4-1/2” tubing e. Planning to pull one string at a time f. If tubing strings will only pull together, we will need to install and test a dual bore insert first 4. Pull TWCs / BPVs 5. Cut short string a. RU EL to short string b. RIH and cut just above Kobe block at 10,017’ MD c. RD EL 6. Unseat Short string and POOH with 2-7/8” x 2-3/8” tubing 7. Unseat Long string and POOH with 2-7/8” tubing, Kobe block, and tail pipe 8. RIH and set 9-5/8” plug at ±9,225’ MD (8,936’ TVD) to abandon the Granite Point Middle Kenai Oil Pool 9. After set, tag plug with EL or work string to confirm depth 10.MIT to 2250psi (charted) down 9-5/8” casing against CIBP a. Proves plug and casing integrity b. Provide state with 48hr witness notification c. 8936 TVD * 0.25 = 2234psi 11. MU 4-1/2” completion a. SSSV at ±350’ MD b. At least a 25’ MD shoe track as close to CIBP as practical c. Confirm well has a passing / valid no flow test before running completion d. Would need dual SSSV’s and packer if not a no-flow well at time of RWO 12. RIH and land completion just above existing 9-5/8” plug 13. Circulate cement into 4-1/2” x 9-5/8” annulus a. This annulus cement and shoe track will finish the abandonment of the Middle Kenai Oil Pool b. Target ToC at ±3000’ MD (2975’ MD) c.This brings ToC above the surface casing shoe, and ~250’ above the top Granite Point Gas Pool 14. ND BOP, NU tree and test 15. WoC Superseded Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) Post-Rig Procedure and Snubbing Operations 1. Obtain CBL. Submit results to AOGCC 2. MIT-IA to 2250psi (charted) 3. Snubbing prep a. Review sundry b. Review COA’s c. Review IRP15, specifically all shall and must statements 4. RU and test snubbing stack (per attachment) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High c. Subbing stack will be rigged up to the top of the production tree after HWO BOPE is removed d. Snubbing stack will only be added for the final operation 5. PU 2-3/8” jointed pipe workstring a. Well will be still loaded with fluid, and isolated from formation b. No snubbing operations needed for RIH c. Ensure workstring has a float installed for forward circulation only d. Test/chart float to 3400psi per IRP15 i. 2600psi N2 pressure ii. 2600psi * 1.3 = 3380psi 6. RIH with 2-3/8” jointed workstring and once on bottom blow well dry with N2 via forward circulation a. Pump N2 down workstring b. Take returns out 4-1/2” x 2-3/8” annulus 7. Trap 2600psi nitrogen pressure on wellbore (or less per OE) 8. Snub OOH with 2-3/8” workstring 9. Demob HWO / snubbing unit and crew E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3000psi high 3. Ensure CBL approval from AOGCC before perforating 4. RIH and perforate Gas Sands from ±5,653’ - ±7,730’ MD (±5,500’ - ±7,521’ TVD) per RE/Geo 5. RDMO EL Note: Hilcorp will likely want to perf and produce above the requested top perf from above. Before perf’ing above ±5,653’ MD (±5,500’ TVD) Hilcorp must review current well status / perfs / plugs / pressures with the agency and obtain additional approval. FYI Superseded Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) CONTINGENCY plug: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and PT lines to 3000psi (or higher if needed) 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 3000psi high 5. Set 4-1/2” isolation plug or patch per OE 6. RDMO Nitrogen and EL CONTINGENCY CT Cleanout: (if any zone brings in excessive fill and needs to be cleaned out) 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 3000psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD or as deep as practical a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning 5. Once cleanout is completed, blow well down with nitrogen 6. RDMO CT Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. HWO BOP Drawing (TSI) 6. Snubbing BOP diagram (TSI) 7. HWO Fluid/Flow Diagrams (TSI) 8. IRP15 compliance matrix 9. Snubbing stack stabilization diagram (TSI) 10. Fox CT BOP Diagram 11. Offshore Nitrogen procedure 12. RWO Sundry Change Form Superseded Version #3 (11/19/24) Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) Well Name: Granite Point State 18742 17A (Anna-17A) API Number: 50-733-20311-01-00 Current Status: Offline JP Oil Producer Leg: Leg #2 (East corner) Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 213-049 First Call Engineer: Ryan Rupert (907) 301-1736 (c) Second Call Engineer: Dan Marlowe (907) 398-9904 (c) Worst Expected BHP: 3,677 psi @ 7,521’ TVD 9.4ppg mud from 2013 sidetrack Max. Potential Surface Pressure: 2924 psi Using 0.1 psi/ft Brief Well Summary Anna-17A was sidetracked to its current location in 2013. New 9-5/8” casing was run back to surface and cemented. This provides one of the few wells in Granite Point that has cement well uphole above the oil pools. The well has been SI since 2018 due to low inflow and high water cut. These factors make Anna-17A a good candidate to recomplete uphole and target gas production from the Granite Point gas Pool. The goal of this project is to abandon the existing oil completion, and recomplete for uphole gas production Updates in red from 11/19/24 revision Pertinent wellbore information: x Max inclination above PBTD: 70 degrees below 11,600’ MD x 2013 sidetrack o Existing 9-5/8” was cut/pull from ~100’ below 13-3/8” shoe o Cement plug laid in, and kicked off for sidetrack o New 9-5/8” casing and 7” liner ran o Initial completion tested Granite Point Hemlock Oil Pool (wet) x 2015 Recomplete to Tyonek oil sands (Middle Kenai Oil Pool) o Set 7” CIBP at 11,875’ MD and dump bail 30’ of cement to P&A the Granite Point Hemlock Oil Pool o CBL of 9-5/8” casing shows ToC at 3,125’ MD o PT of casing to 1500psi GOOD (15 mins) o TCP Middle Kenai Oil Pool sands in 7” and 9-5/8” casing o Ran current dual JP completion x 7/30/15: passed No Flow Test x 8/15/15: Last drift of short string. 1.75” bailer to 10,017’ MD. 1.85” gauge ring can’t pass 9458’ SLMD x 12/7/15: Found scale in tubing tail, and punched above it from 10,030 – 10,036’ to reestablish communication x 11/2/16: last time standing valve was pulled. Had to bail scale Version #3 (11/19/24) Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) Pools in Anna-17A: x Top Granite Point Gas Pool: 3,272’ MD (3,230’ TVD) x Top Granite Point Middle Kenai Oil Pool: 8610’ MD (8,378’ TVD) x Top Granite Point Hemlock Oil Pool: 11,956 MD (10,791’ TVD) o Already P&A’d via CIBP and cement at 11,875’ MD (10,763’ TVD) Pressures: x Open Granite Point Middle Kenai Oil Pool perfs (C-sands) o 2015 RWO had 6.8ppg diesel in well before shooting the C sands o Well went on vac after perforating o No nearby injection. o Reservoir P today < 6.8ppg x Proposed Granite Point Gas pool sands o Base at 7,521’ TVD o Was drilled in 2013 with mud weights at 9.4PPG and less o 9.4 ppg * 0.052 * 7,521 ft TVD = 3,677 psi o 0.1 psi/ft * 7,521 ft TVD = 752 psi o MPSP from Gas Sands = 3677 – 752 = 2924psi x 1977 D&C obtained a 12.3ppg LOT at 13-3/8” shoe (3,459’ TVD) x The proposed Gas perfs in Anna-17A are from 5,550’ - 7,521’ TVD o 9.4 ppg * 0.052 * 7,521 ft TVD = 3,677 psi o 0.1 psi/ft * (7,521 ft TVD – 5,550 ft TVD) = 197 psi o 3,677 psi – 197 psi = 3480 psi (at 5,500 ft TVD) o 3480 psi / 0.052 / 5,500’ TVD = 12.1ppg x We can perf up to 5,653’ MD (5,500’ TVD) in Anna-17A and stay under the 12.3ppg FIT 9-5/8” Cement (2013): x 12-1/4” hole drilled off a cement plug at 13-3/8” casing shoe x String was cemented with 450bbls of 12.5ppg lead cement followed by 45bbls of 15.8ppg tail cement x 119bbls losses throughout job x 6/14/15 CBL shows ToC at 3,125’ MD. HWO Conditions x Operations shall be 24hrs continuous x Traditional well control approach will be implemented x Filtered Inlet water (FIW) will be used as kill weight fluid (8.4ppg or greater) x KWF will be a barrier at all times during HWO operations x Snubbing operations will only be performed at the very end of the job (see below) x Team Snubbing’s BOP stack will be used for this operation (see attachment) Version #3 (11/19/24) Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) HWO Procedure: 1. MIRU Team Snubbing Hydraulic Workover (HWO) Unit (Snubbing International, Alberta, Canada) 2. Circulate / Bullhead kill well: a. Work over fluid will be fresh water (8.33ppg) or heavier b. Ensure any wellbore fluids are fully displaced with KWF via circulation and bullheading c. WBV = 722 bbls i. Long string: 58 bbls ii. Short string: 56 bbls iii. IA above tubing tail: 554 iv. 7” Liner below tubing tail: 54 bbls 3. Set BPVs / TWCs, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Test to cover existing 2-7/8” and 2-3/8” tubing, plus new 4-1/2” tubing e. Planning to pull one string at a time f. If tubing strings will only pull together, we will need to install and test a dual bore insert first 4. Pull TWCs / BPVs 5. Cut short string a. RU EL to short string b. RIH and cut just above Kobe block at 10,017’ MD c. RD EL 6. Unseat Short string and POOH with 2-7/8” x 2-3/8” tubing 7. Unseat Long string and POOH with 2-7/8” tubing, Kobe block, and tail pipe 8. RIH and set 9-5/8” plug at ±9,225’ MD (8,936’ TVD) to abandon the Granite Point Middle Kenai Oil Pool 9. After set, tag plug with EL or work string to confirm depth Version #3 (11/19/24) Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) 10. PU pipe and RIH with 9-5/8” cement retainer (may use 2-7/8” work string or 4-1/2” completion tubing. TBD) 11. Set 9-5/8” cement retainer at ±8,750’ MD (8,514’ TVD): 491’ above top perf 12. Downsqueeze 130bbls of cement to abandon the Granite Point Middle Kenai Oil Pool a. 9-5/8” volume below retainer = 48bbls b. 7” volume down to 100’ below bottom perf = 82bbls c. Attempt to pump keeping surface pressures below 1000psi d. If unable to pump at least 2.0bpm while staying below max pressure, ok to increase max surface pressure to 2000psi and frac away the remainder of the job i. 9-5/8” 47# P-110 burst rating @ 9440psi * 70% = 6608psi ii. 7” 29# P-110 burst rating @ 11,220psi * 70% = 7854psi iii. Deepest 9-5/8” casing at 9403’ MD / 9128’ TVD iv. 15.8ppg cement @ 9128’ TVD = 7500psi hydrostatic pressure v. 8.4ppg overburden outside 9-5/8” casing at 9128’ TVD = 3987psi vi. Net hydroststic force exerted by column of cement: 7263 – 3987 = 3513psi vii. 70% burst @ 6608psi – 3513psi net hydrostatic = 3095psi allowable applied pressure viii. 12/12/13: FIT passed to 15.0ppg at 9-5/8" casing shoe at 10,483' MD / 10,025' TVD 13. Unsting from cement retainer and lay in 5.5bbls on top targeting ToC = 8600’ MD (8,369’ TVD) a. Volume in 9-5/8” from 8600’ MD to retainer at 8750’ MD = 5.5bbls b. This brings ToC to top Granite Point Middle Kenai Oil Pool (8610’ MD / 8378’ TVD) 14. MIT to 2200psi (charted) down 9-5/8” casing against cement + retainer a. Proves plug and casing integrity b. Provide state with 48hr witness notification c. 8514 TVD * 0.25 = 2129psi 15. MU 4-1/2” completion a. SSSV at ±350’ MD b. Target bottom of completion at ±8500’ MD / 8272’ TVD (±100’ above existing ToC) 16. RIH and land completion Will include 30’ shoe track, with PBTD at 8470’ MD per Ryan Rupert email 11/20/24 attached. -bjm 17. Circulate 295bbls cement into 4-1/2” x 9-5/8” annulus a. Target ToC at ±3000’ MD (2975’ MD) b. 4-1/2” x 9-5/8” annulus volume from 3000’ – 8500’ = 295bbls c. This brings ToC above the surface casing shoe, and ~250’ above the top Granite Point Gas Pool 18. ND BOP, NU tree and test 19. WoC Version #3 (11/19/24) Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) Post-Rig Procedure and Snubbing Operations 1. Obtain CBL. Submit results to AOGCC 2. MIT-IA to 2250psi (charted) 3. Snubbing prep a. Review sundry b. Review COA’s c. Review IRP15, specifically all shall and must statements 4. RU and test snubbing stack (per attachment) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High c. Subbing stack will be rigged up to the top of the production tree after HWO BOPE is removed d. Snubbing stack will only be added for the final operation 5. PU 2-3/8” jointed pipe workstring a. Well will be still loaded with fluid, and isolated from formation b. No snubbing operations needed for RIH c. Ensure workstring has a float installed for forward circulation only d. Test/chart float to 3400psi per IRP15 i. 2600psi N2 pressure ii. 2600psi * 1.3 = 3380psi 6. RIH with 2-3/8” jointed workstring and once on bottom blow well dry with N2 via forward circulation a. Pump N2 down workstring b. Take returns out 4-1/2” x 2-3/8” annulus c. Ensure returns are taken directly to an open top tank, and nitrogen is vented appropriately d. Returns are not to be taken ‘inside’ to a mud system e. Mud / pumping system will be RDMO by this step 7. Trap 2600psi nitrogen pressure on wellbore (or less per OE) 8. Snub OOH with 2-3/8” workstring 9. Demob HWO / snubbing unit and crew E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 3000psi high 3. Ensure CBL approval from AOGCC before perforating 4. RIH and perforate Gas Sands from ±5,653’ - ±7,730’ MD (±5,500’ - ±7,521’ TVD) per RE/Geo 5. RDMO EL Note: Hilcorp will likely want to perf and produce above the requested top perf from above. Before perf’ing above ±5,653’ MD (±5,500’ TVD) Hilcorp must review current well status / perfs / plugs / pressures with the agency and obtain additional approval. FYI Version #3 (11/19/24) Recomplete for Gas HWO Well: Granite Point State 18742 17A (Anna-17A) CONTINGENCY plug: (if any zone makes unwanted solids or water) 1. RU nitrogen to tubing and PT lines to 3000psi (or higher if needed) 2. Pressure up on tubing and displace water back into formation 3. MIRU E-line and pressure control equipment 4. PT lubricator to 250psi low / 3000psi high 5. Set 4-1/2” isolation plug or patch per OE 6. RDMO Nitrogen and EL CONTINGENCY CT Cleanout: (if any zone brings in excessive fill and needs to be cleaned out) 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250psi low / 3000psi high 3. MU FCO BHA 4. RIH and cleanout to PBTD or as deep as practical a. Working fluid will be water (8.33ppg or greater) b. Take returns to surface up the CT x tubing annulus c. Add foam and nitrogen as necessary to carry solids to surface d. Can use GL to assist with hole cleaning 5. Once cleanout is completed, blow well down with nitrogen 6. RDMO CT Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. HWO BOP Drawing (TSI) 6. Snubbing BOP diagram (TSI) 7. HWO Fluid/Flow Diagrams (TSI) 8. IRP15 compliance matrix 9. Snubbing stack stabilization diagram (TSI) 10. Fox CT BOP Diagram 11. Offshore Nitrogen procedure 12. RWO Sundry Change Form Updated by: CRR 10/23/24 SCHEMATIC Anna Platform Well No. AN-17A Completion Date: 06/22/2015 Cement Details 13-3/8”17-1/2” hole: Cemented with 621bbls 13.4ppg Class G lead followed by 72bbls 15.2ppg tail . No losses. Saw returns to surface.ToC to surface. 9-5/8”12-1/4” Hole: Cemented with 450bbls 12.5ppg lead class cement, and 45bbls 15.8ppg tail cement. 119bbl losses throughout displacement.6/14/15 shows ToC at 3,125’ MD API # 50-733-20311-01 C 1 B 7” 9 5/8” 13 3/8” 20” 9 5 8 30” 6 7 4 3 2 9,403’ 10 XO IBT 9,220’ 22° S-Sleeve LWR 12,055’ 69° Top of Cement - 11,845’ 10 A Tbg Punch 12/7/15 @ 10,029’-10,036’ PBTD = 11,845’ MD (11,050’ TVD) R R CASING AND TUBING DETAIL SIZE (in) WT (lbs/ft) GRADE CONN ID (in) TOP (ft) BTM (ft) 30 94 X-55 - - Surf - 20 91.5 X-52 - 19.124 Surface 610 13-3/8 54.5, 61, 68, 72 K-55 & L-80 BTC 12.347 Surface 3,514 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 Tubing Long String 2-7/8 6.4 L-80 EUE 2.441 Surface 9,223’ 2-7/8 6.4 L-80 IBT SC 2.441 9,223’ 10,017’ Short String 2-7/8 6.4 L-80 EUE 2.441 Surface 9,197’ 2-3/8 4.6 L-80 IBT SC 1.995 9,197’ 10,017’ Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status C5B 9,241' 9,248' 8,980' 8,986' 7' 5 6/18/2015 Open C5B 9,260' 9,279' 8,997' 9,014' 19' 5 6/18/2015 Open C7A 9,541' 9,554' 9,253' 9,264' 13' 5 6/18/2015 Open C7A 9,568' 9,580' 9,277' 9,288' 12' 5 6/18/2015 Open C7C 9,652' 9,669' 9,352' 9,367' 17' 5 6/18/2015 Open C7C 9,678' 9,704' 9,374' 9,397' 26' 5 6/18/2015 Open C7E 9,758' 9,781' 9,444' 9,464' 23' 5 6/18/2015 Open C8B 9,919' 9,969' 9,581' 9,623' 50' 5 6/18/2015 Open C8C 10,013' 10,074' 9,659' 9,708' 61' 5 6/18/2015 Open C9B 10,420' 10,433' 9,976' 9,985' 13' 5 6/18/2015 Open C9C 10,580' 10,590' 10,091' 10,098' 10' 5 6/18/2015 Open C9C 10,634' 10,648' 10,129' 10,139' 14' 5 6/18/2015 Open C10 10,967' 10,972' 10,349' 10,352' 5' 5 6/18/2015 Open C11 11,440' 11,455' 10,596' 10,603' 15' 5 6/18/2015 Open C11 11,469' 11,499' 10,609' 10,621' 30' 5 6/18/2015 Open Hemlock 11,969' 11,983' 11,224’ 11,237' 14' 6 6/14/2015 Isolated Hemlock 12,047' 12,067' 11,299’ 11,319’ 20' 6 6/14/2015 Isolated Hemlock 12,084' 12,450' 11,335’ 11,689’ 366' 6 6/14/2015 Isolated Hemlock 12,450' 12,453' 11,689’ 11,692’ 3' 12 6/14/2015 Isolated Item Description ID (in) OD (in) Depth (ft) RKB - - - 1 Tubing Hanger 3 1/2" EUE Lift and Suspension 2.441 2.875 51’ 2 XO 2 7/8" 8Rnd EUE X 2 7/8" IBT SCC 2.441 2.875 9,223’ 3 XO 2 7/8" IBT SCC X 2 7/8" EUE 2.441 2.875 10,015’ 4 Kobe cavity 2 1/2" - 5.875 10,017’ 5 "R"- Landing Nipple 2.188 3.680 10,023’ 6 Ratcheting Mule Shoe 2.441 4.000 10,056’ 7CIBP 11,875’ 8 Packer: 7" 26-32# Model "D" Permanent Pkr 3.250 5.810 11,900’ Concentric Packer Adapter 3.250 5.810 11,901’ Seal Bore Extension: 3.250'' X 5' 3.250 4.250 11,902’ Tbg Adapter:2-7/8'' EUE Box 2.810 4.990 11,906 ‘ 9 "R" - Landing Nipple 2.188 3.669 11,915’ 10 Sliding Sleeve 2 7/8'', "R" 2.188 3.190 12,055’ Pyrotechnic Delay Firing Head - 3.125 12,077’ Blank Safety Spacer: 4 1/2'' - 4.500 12,078‘ 6 SPF SDP TCP Assembly: 4.5'' Top Shot - 4.500 12,084’ 6 SPF SDP TCP Assembly: 4.5'' Btm Shot - 4.500 12,450’ Lower Firing Adapter: 4.5'' - 3.125 12,451’ Pyrotechnic Delay Firing Head - 3.125 12,453’ Short String RKB - - - A Tbg hanger - - 50’ B XO 2 7/8" 8rnd EUE X 2 3/8" IBT SCC 1.995 3.680 9,197’ C XO 2 3/8" IBT SCC X 1.25 NPT 1.250 2.700 10,017’ Updated by: JLL 10/23/24 PROPOSED Anna Platform Well No. AN-17A Completion Date: FUTURE Cement Details 13-3/8”17-1/2” hole: Cemented with 621bbls 13.4ppg Class G lead followed by 72bbls 15.2ppg tail . No losses. Saw returns to surface.ToC to surface. 9-5/8”12-1/4” Hole: Cemented with 450bbls 12.5ppg lead class cement, and 45bbls 15.8ppg tail cement. 119bbl losses throughout displacement.6/14/15 shows ToC at 3,125’ MD 4-1/2 X 9-5/8”Target TOC ±3,000 MD API # 50-733-20311-01 1 7” 9 5/8” 13 3/8” 20” 5 4 30” 3 9,403’ 6 S-Sleeve LWR 12,055’ 69° Top of Cement - 11,845’ 10 PBTD = 11,845’ MD (11,050’ TVD) 2 R CASING AND TUBING DETAIL SIZE (in) WT (lbs/ft) GRADE CONN ID (in) TOP (ft) BTM (ft) 30 94 X-55 - - Surf - 20 91.5 X-52 - 19.124 Surface 610 13-3/8 54.5, 61, 68, 72 K-55 & L-80 BTC 12.347 Surface 3,514 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 Tubing 4-1/2”Surf ±9,200’ Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status ±5,653’ ±7,730’ ±5,500’ ±7,521’ Future Proposed JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item Tubing Hanger 1 ±350’ ±350’ SSSV 2 ±9,225’ ±8,936’ CIBP Superseded Updated by: JLL 10/23/24 PROPOSED Anna Platform Well No. AN-17A Completion Date: FUTURE Isolated Jewelry Details Item Description ID (in) OD (in) Depth (ft) 3CIBP 11,875’ 4 Packer: 7" 26-32# Model "D" Permanent Pkr 3.250 5.810 11,900’ Concentric Packer Adapter 3.250 5.810 11,901’ Seal Bore Extension: 3.250'' X 5' 3.250 4.250 11,902’ Tbg Adapter:2-7/8'' EUE Box 2.810 4.990 11,906 ‘ 5 "R" - Landing Nipple 2.188 3.669 11,915’ 6 Sliding Sleeve 2 7/8'', "R" 2.188 3.190 12,055’ Pyrotechnic Delay Firing Head - 3.125 12,077’ Blank Safety Spacer: 4 1/2'' - 4.500 12,078‘ 6 SPF SDP TCP Assembly: 4.5'' Top Shot - 4.500 12,084’ 6 SPF SDP TCP Assembly: 4.5'' Btm Shot - 4.500 12,450’ Lower Firing Adapter: 4.5'' - 3.125 12,451’ Pyrotechnic Delay Firing Head - 3.125 12,453’ Isolated Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status C5B 9,241' 9,248' 8,980' 8,986' 7' 5 6/18/2015 Future C5B 9,260' 9,279' 8,997' 9,014' 19' 5 6/18/2015 Future C7A 9,541' 9,554' 9,253' 9,264' 13' 5 6/18/2015 Future C7A 9,568' 9,580' 9,277' 9,288' 12' 5 6/18/2015 Future C7C 9,652' 9,669' 9,352' 9,367' 17' 5 6/18/2015 Future C7C 9,678' 9,704' 9,374' 9,397' 26' 5 6/18/2015 Future C7E 9,758' 9,781' 9,444' 9,464' 23' 5 6/18/2015 Future C8B 9,919' 9,969' 9,581' 9,623' 50' 5 6/18/2015 Future C8C 10,013' 10,074' 9,659' 9,708' 61' 5 6/18/2015 Future C9B 10,420' 10,433' 9,976' 9,985' 13' 5 6/18/2015 Future C9C 10,580' 10,590' 10,091' 10,098' 10' 5 6/18/2015 Future C9C 10,634' 10,648' 10,129' 10,139' 14' 5 6/18/2015 Future C10 10,967' 10,972' 10,349' 10,352' 5' 5 6/18/2015 Future C11 11,440' 11,455' 10,596' 10,603' 15' 5 6/18/2015 Future C11 11,469' 11,499' 10,609' 10,621' 30' 5 6/18/2015 Future Hemlock 11,969' 11,983' 11,224’ 11,237' 14' 6 6/14/2015 Isolated Hemlock 12,047' 12,067' 11,299’ 11,319’ 20' 6 6/14/2015 Isolated Hemlock 12,084' 12,450' 11,335’ 11,689’ 366' 6 6/14/2015 Isolated Hemlock 12,450' 12,453' 11,689’ 11,692’ 3' 12 6/14/2015 Isolated Superseded Updated by: JLL 11/19/24 PROPOSED Anna Platform Well No. AN-17A Completion Date: FUTURE PTD: 213-049 API: 50-733-20311-01-00 Cement Details 13-3/8”17-1/2” hole: Cemented with 621bbls 13.4ppg Class G lead followed by 72bbls 15.2ppg tail . No losses. Saw returns to surface.ToC to surface. 9-5/8”12-1/4” Hole: Cemented with 450bbls 12.5ppg lead class cement, and 45bbls 15.8ppg tail cement. 119bbl losses throughout displacement.6/14/15 shows ToC at 3,125’ MD 4-1/2 X 9-5/8”Target TOC ±3,000’ MD API # 50-733-20311-01 1 7” 9 5/8” 13 3/8” 20” 5 4 30” 3 9,403’ 6 S-Sleeve LWR 12,055’ 69° Top of Cement - 11,845’ 10 PBTD =±8,470’ MD (±8,242’ TVD) 2 R CASING AND TUBING DETAIL SIZE (in) WT (lbs/ft) GRADE CONN ID (in) TOP (ft) BTM (ft) 30 94 X-55 - - Surf - 20 91.5 X-52 - 19.124 Surface 610 13-3/8 54.5, 61, 68, 72 K-55 & L-80 BTC 12.347 Surface 3,514 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 Tubing 4-1/2” Surf ±8,500’ Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status ±5,653’ ±7,730’ ±5,500’ ±7,521’ Future Proposed JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item Tubing Hanger 1 ±350’ ±350’ SSSV 2 ±8,750’ ±8,514’ Cement Retainer w/ 5bbls cement (TOC ±8,610’) Updated by: JLL 11/19/24 PROPOSED Anna Platform Well No. AN-17A Completion Date: FUTURE PTD: 213-049 API: 50-733-20311-01-00 Isolated Jewelry Details Item Description ID (in) OD (in) Depth (ft) 3CIBP 11,875’ 4 Packer: 7" 26-32# Model "D" Permanent Pkr 3.250 5.810 11,900’ Concentric Packer Adapter 3.250 5.810 11,901’ Seal Bore Extension: 3.250'' X 5' 3.250 4.250 11,902’ Tbg Adapter:2-7/8'' EUE Box 2.810 4.990 11,906 ‘ 5 "R" - Landing Nipple 2.188 3.669 11,915’ 6 Sliding Sleeve 2 7/8'', "R" 2.188 3.190 12,055’ Pyrotechnic Delay Firing Head - 3.125 12,077’ Blank Safety Spacer: 4 1/2'' - 4.500 12,078‘ 6 SPF SDP TCP Assembly: 4.5'' Top Shot - 4.500 12,084’ 6 SPF SDP TCP Assembly: 4.5'' Btm Shot - 4.500 12,450’ Lower Firing Adapter: 4.5'' - 3.125 12,451’ Pyrotechnic Delay Firing Head - 3.125 12,453’ Isolated Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt SPF Date Status C5B 9,241' 9,248' 8,980' 8,986' 7' 5 6/18/2015 Isolated (Future) C5B 9,260' 9,279' 8,997' 9,014' 19' 5 6/18/2015 Isolated (Future) C7A 9,541' 9,554' 9,253' 9,264' 13' 5 6/18/2015 Isolated (Future) C7A 9,568' 9,580' 9,277' 9,288' 12' 5 6/18/2015 Isolated (Future) C7C 9,652' 9,669' 9,352' 9,367' 17' 5 6/18/2015 Isolated (Future) C7C 9,678' 9,704' 9,374' 9,397' 26' 5 6/18/2015 Isolated (Future) C7E 9,758' 9,781' 9,444' 9,464' 23' 5 6/18/2015 Isolated (Future) C8B 9,919' 9,969' 9,581' 9,623' 50' 5 6/18/2015 Isolated (Future) C8C 10,013' 10,074' 9,659' 9,708' 61' 5 6/18/2015 Isolated (Future) C9B 10,420' 10,433' 9,976' 9,985' 13' 5 6/18/2015 Isolated (Future) C9C 10,580' 10,590' 10,091' 10,098' 10' 5 6/18/2015 Isolated (Future) C9C 10,634' 10,648' 10,129' 10,139' 14' 5 6/18/2015 Isolated (Future) C10 10,967' 10,972' 10,349' 10,352' 5' 5 6/18/2015 Isolated (Future) C11 11,440' 11,455' 10,596' 10,603' 15' 5 6/18/2015 Isolated (Future) C11 11,469' 11,499' 10,609' 10,621' 30' 5 6/18/2015 Isolated (Future) Hemlock 11,969' 11,983' 11,224’ 11,237' 14' 6 6/14/2015 Isolated Hemlock 12,047' 12,067' 11,299’ 11,319’ 20' 6 6/14/2015 Isolated Hemlock 12,084' 12,450' 11,335’ 11,689’ 366' 6 6/14/2015 Isolated Hemlock 12,450' 12,453' 11,689’ 11,692’ 3' 12 6/14/2015 Isolated Anna Platform An-17A Current 03/16/2015 DSA, 13 5/8 3M X 13 5/8 3M w/ full set of lockpins for packoff on mandrel hanger Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Casing spool, CIW-WF, 21 ¼ 2M X 13 5/8 3M, w/ 2-2 1/16 5M EFO, X bottom prep Casing head, CIW-WF, 21 ¼ 2M X SOW, w/ 2- 2 1/16 2M EFO Tree assy, dual block, CIW-F, 11 5M X 3 1/8 5M X 3 1/8 5M, prepped on 5 3/64 center, 3'’ CIW seal pockets, ½ npt control line exits An-17A 20 X 13 3/8 X 9 5/8 X 2 7/8 X 2 7/8 Tubing hanger, CIW-DCB, 11 X 3 ½ EUE lift X 3 ½ IBT susp, w/ ¼ non cont control line ports, 5 3/64 centers X2 control lines Anna Platform An-17A Proposed 10/09/2024 Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Upper master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, EE trim BHTA, Bowen, 4 1/16 5M FE x 7'’ Bowen quick union top DSA, 13 5/8 3M X 13 5/8 3M w/ full set of lockpins for packoff on mandrel hanger Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X-bottom prep Casing spool, CIW-WF, 21 ¼ 2M X 13 5/8 3M, w/ 2- 2 1/16 5M EFO, X bottom prep Casing head, CIW-WF, 21 ¼ 2M X SOW, w/ 2- 2 1/16 2M EFO An-17A 20 X 13 3/8 X 9 5/8 X 4 1/2 Tubing hanger, CIW-DCB-EN- CCL, 11 X 4 ½ EUE 8rd lift X 4 ½ EUE 8rd susp, w/4'’ type H BPV profile, w/ ½npt cont control line ports, 17-4ph material X2 control lines 20'’13 3/8'’ 9 5/8'’ 4 ½’’ IRP Chapter / Component Compliance RequirementIRP 15.01.07BHA components fit in snubbing stackNo BHA is present as it is a slick string. Snubbing stack is correct for operationMinnium one plug in tubingFloat will be installed (one way check valve).IRP 15.01.08Snubbing forces calculated on site Will be done on site, Hilcorp responsibility with TSI input.Tubing buckling calculationsWill be done on site, Hilcorp responsibility with TSI input.Pipe heavy calculations done for MPSPCalculations will be conducted on site by Hilcorp personnel and Tsi input. Force = Pressure X Area (Area = .7854 X Diameter XDiameter). This lift force will deducted from total pipe weight.Tubing hanger calculations Will be done on site, Hilcorp responsibility with TSI inputRotary torque calculations No rotary requiredIRP 15.01.08.02Prejob calculations Will be done on site, Hilcorp responsibility with TSI inputIRP 15.01.09.01Explosive mixture in casing Equalize to bleed line to purge the stackIRP 15.01.12Supervisory control Hilcorp Wellsite Manager (WSM)IRP 15.02.01Plugs shall be tested to 1.3x BHPFloat will be tested prior to use. Recorded test and onsite prior to snubbing job. 2600psi nitrogen pressure. 1.3 * 2600psi =3380psi test pressure for float.IRP 15.03.01Regulatory requirements must befollowed for all primary BOP equipmentAOGCC Regulation/BOP testInstall shear ram as the lowest primary BOPBlind shear ram in lowermost position planned per sundryMinimum of one hole volume on site Hilcorp will have TSI's pump, and unlimited filtered inlet water on locationIRP 15.06.01Hazard Assesments PJSM will review hazard assesments per TSI JSA / SOP for Tripping Pipe Into WellboreIRP 15.06.02Hazards PJSM will review IRP 15.06.02 Table 8 Hazard RegisterIRP 15.07.2Joint Safety MeetingsHilcorp WSM will hold JSM prior to performing work with all vendors on site. Agendawill include a risk assesment, specific safety requirements, supervisory control, wellshut in procedures, responsibllities, egress, and SIMOPS.IRP 15.08.02Pre-job calculations Will be done on site, Hilcorp responsibility with TSI inputIRP 15.08.04Primary BOPE tested per regulations AOGCC witnessed BOP testIRP 15.08.05Contingency PracticesPJSM will review different failure mechanisms and the corrective action to then take place as detailed in IRP 15.8.5IRP 15.08.09Setting Jack Pressure Follow steps 1-11 in IRP 15.8.9 to set hydraulic jack pressureIRP 15.08.13Landing tubing hangerN/A. No hanger operations while snubbing /DE^/KE^ΘdK>ZE^ϭΣ&Zd/KE>E'h>ZϬ͘ϬϬ͘ϬϬϬ͘ϬϬϬцϬ͘ϬϯϬϬ͘ϬϭϱϬ͘ϬϬϱццццϭͬϭϲцϬ͘ϬϬϬϬ Ϭ͘ϬϬϭ(1(5*<6(59,&(6,&21EKd͗t/E>K^^KEϵϬ&d,/',d&ZKDsZ'tdZ>KtdKZ/>>&>KKZϮϰϯϭͬϮΗϮϰϬϭͬϮΗϮϱϮϭͬϮΗϮϲϮϭͬϮΗϬΗϭϱΗϮϲϭΗtKZ<&>KKZ,/',dϯϬϮϭͬϮΗ'hzt/Z^W^yWdW<dE^/KEϰ͕ϱϴϬ>^KEϭ͕ϬϬϬ>WZͲdE^/KE͘ϯͬϰ/tZ/W^ϲyϭϵt/ZZKW'hzϭϱϬΖ'hzϭϱϬΖ'hzϭϱϬΖ'hzϭϱϬΖ6'a$11$B*8</,1(6^,dϭK&ϭZs͗$5&+&'EZ>EKd^͗ϭ͘h͘E͘K͘>>&/>>dt>^dKϭͬϰΗKEd/EhKh^͘Ϯ͘h͘E͘K͘>>hddt>^dKϭͬϰΗKEd/EhKh^͘ϯ͘^>t>>>dh/E'͘ϰ͘^d/<E&>hyͲKZt>/E'WZKhZ^Z/EdZ,E'>KEEYh/s>Ed^/^͘ϱ͘KEKd^>Zt/E'͘ϲ͘/&/EKhd^<͘Z/'ηZtE͗,<͗WWZKs͗d͗^,d^/͗WZK:d/KE͗^ϬϮdKW>s>^^D>z/ͲͲ/h^dKDZ͗&/>͗d/d>͗dD^Eh/E'/EdZEd/KE>^,dd/d>͗'EZ>^^zd^ϭϬϭt'η͗ϮϬϮϰͲϭϭͲϬϭ>^<^Eh/E'W<'ϭϴϬϯϯΕd,/E&KZDd/KE/E>h/Ed,/^KhDEd/^WZKWZ/dZzE^,>>EKdZWZKh͕dZE^&ZZ͕KZ/^>K^dKKd,Z^͕&KZEzWhZWK^t,d^KsZ͕t/d,Khdd,tZ/ddEhd,KZ/d/KEK&/KEEZ'z^Zs/^͘Ϯϯϴϲϵ͘ϯ>td͗ KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Granite Pt St 18742 17A (PTD 213-049)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 From:Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent:Tuesday, November 19, 2024 9:19 AM To:McLellan, Bryan J (OGC) Cc:Ryan Rupert; Dan Marlowe; Juanita Lovett Subject:RE: [EXTERNAL] Granite Pt St 18742-15 (PTD 213-049) RWO sundry Attachments:V3_Anna-17A_AOGCC Wellwork Procedure(Nov-2024).docx; An-17A Proposed 2024-11-19.pdf Bryan- Please see V3 attached procedure. There is additional detail now in the downsqueeze step (#12) showing the math relating to casing burst strength. Max treating pressure has been reduced to 2000psi. There was an FIT at the 9-5/8” casing shoe in 2013 which passed to 15.0ppg I also plan on using a ~30’ shoe track at the bottom of the 4-1/2” tubing. This keeps end of tubing at 8500’, and new PBTD at 8470’ MD. Updated proposed schematic now reƲects this. Thanks, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, November 18, 2024 5:33 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: [EXTERNAL] Granite Pt St 18742-15 (PTD 213-049) RWO sundry Ryan, Regarding the squeeze pressure, I’m concerned that by going to 3000 psi, you might be approaching the burst pressure of the 9-5/8” casing, depending on the cement density. I think you should limit it to 2000 psi injection pressure to be safely below burst pressure, but above frac pressure. Do you know what frac pressure at the 9-5/8” casing shoe was? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Monday, November 18, 2024 3:39 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: RE: [EXTERNAL] Granite Pt St 18742-15 (PTD 213-049) RWO sundry Bryan- Per our conversation, please see attached for redlines V2 of this procedure addressing the below concerns. We’d like to MIRU on Friday 11/22. Thanks, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Wednesday, November 13, 2024 5:40 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] Granite Pt St 18742-15 (PTD 213-049) RWO sundry Ryan, The AOGCC has reviewed this sundry application and determined that the plan to plug the Middle Kenai Oil Pool with a CIBP above a ~1500’ TVD section of open perfs with multiple isolated sands does not meet the intent of the P&A regulation 20 AAC 25.112(c) that says “Plugging of cased portions of a wellbore must be performed in a manner that ensures that all hydrocarbons … are conƱned to their respective indigenous strata and prevented from migrating into other strata.” The well has many separate sand intervals perforated as shown on the log section below. I suggest setting a Cement retainer instead of the CIBP and squeezing all of the open perfs in one cement job, but there are many ways to go about it. Let me know what you’d like to do. Happy to discuss options. Thanks CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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. 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. M¡.Kenai.Oil Pool • V OF Tib • 41),AI y/yam s THE STATE Alaska Oil and Gas ••,,,:.-s�i��, ofALASIc:A Conservation Commission :- _____ S1f 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov August 17, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 SCANNED SEP 0 3 2015 Anchorage, AK 99524-4027 RE: No-Flow Verification Granite Point State 18742 #17A PTD 2130490 Dear Mr. Golis: On July 30, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Granite Point State 18742 Well #17A located on the Anna Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Granite Point State 18742 Anna #17A prior to the test. The well performance was monitored for 3 hours with resulting flow rates (oil and gas) below the regulatory limits, passing the no-flow test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Granite Point State 18742 Anna #17A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Anna Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e G f '4I ' DATE: 7/31/2015 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector Granite Pt State 18742 Anna #17A Hilcorp Alaska LLC PTD 2130490 713012015: I traveled to the Anna Platform to witness safety valve system tests on all active wells and a no-flow test on Anna #17A. This well is a packerless jet pump completion. Upon arrival I observed the well rigged up as follows: The tubing and tubing-casing (inner) annulus were piped to be in communication prior to the no-flow test measuring equipment. Commingled flow was routed through 2- - inch piping reduced to a 34-inch flow tee with a 30psi test pressure gauge on top and a 3/-inch ball valve in the flow stream ahead of an Erdco ArmorFlo meter (ID #991632). The pressure and flow measurement devices have recent calibrations. Flow from the meter outlet transitioned back to a 2-inch bleed hose which terminated in a partially " water-filled barrel. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 11:00 0/0/325 0 0 open 11:30 0/0/325 0 0 closed 12:00 0.25/0/325 1600 0 open; <1 min to bleed to 0 ,,. 12:30 0/0/325 0 0 open; gas unmeasurable 13:00 0/0/325 0 0 open 13:30 0/0/325 0 0 open 14:00 0/0/325 0 0 open 1 Pressures are T/IA/OA Summary: Anna #17A exhibited the characteristics for a no-flow determination Attachments: Photos (3) SCANNED JUL 1 8 2016 2015-0730 No-Flow GranitePt State_18742_17A jh.docx Page 1 of 3 • No-Flow Test— Granite Pt State 18742 Anna-17A PTD 2130490 Photos by AOGCC Inspector J. Hill 7/30/2015 r vg t •1 1.:',"r'ip ift, els:* 7 :-. , 1...://::, ,, ',;„:„ i\ v",,,,,,,. k It ! lir PR 'lbw ,, . !� ,,� e §1 f F 3 1 , p 7_,..... . 00". ilc ---A, - - +Yrl. / "".��.. iflif 7 � 1!Li! i 7. i , , ' r.• • *,,, 2015-0730 No-Flow GranitePt_State_18742_17Ajh.docx Page 2 of 3 MIIIIIIIIL • • ,,, , ........,.........„. .....,,,......... , .. * • *1 - 4** ,----•%- ,. •,,, -, --- -,...›----,;1'.7--:---- --- *"..s. --,-,..%, • j,1.!. , ;' ,4, , t. .. . , — — ; 1 i•Al l, Ir• , .. 17 100. . ., 44. j ..-.. . I • A.li, 17 le .1 2015-0730_No-Flow_GranitePt_State 18742 17A_jh.docx Page 3 of 3 STATE OF ALASKA RECEIVED • AL ,(A OIL AND GAS CONSERVATION COM, _,SION .IIJL 2 0 2015 REPORT OF SUNDRY WELL OPERATIONS f-i 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well❑ocher: Dual String Jet Pump Completion 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 213-049 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20311-01 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 17A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Pt Field/Hemlock Undefined Oil&Middle Kenai Oil Pools 11.Present Well Condition Summary: Total Depth measured 13,670 feet Plugs measured 11,875 feet true vertical 12,868 feet Junk measured N/A feet Effective Depth measured 11,845 feet Packer measured 11,900 feet true vertical 11,108 feet true vertical 11,157 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 610' 20" 610' 609' 2,110 psi 520 psi Surface 3,514' 13-3/8" 3,514' 3,445' 2,730 psi 1,130 psi Intermediate Production 10,483' 9-5/8" 10,483' 9,789' 6,820 psi 3,330 psi Liner 3,512' 7" 12,915' 12,138' 11,220 psi 8,530 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS-2-7/8" 6.4#/L-80 10,017'(MD) 9,349'(TVD) Tubing(size,grade,measured and true vertical depth) SS-2-7/8"&2-3/8" 6.4# /L-80 10,017'(MD) 9,349'(TVD) 11,900'(MD) Packers and SSSV(type,measured and true vertical depth) Model D Packer 11,157'(TVD) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED AUG 1 0 2015 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 77 0 18 74 80 Subsequent to operation: 0 0 0 70 81 14.Attachments(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL fl Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-263 Contact Trudi Hallett Email thallett a(�hilcorp.com Printed Name // Trudi Hallett Title Operations Engineer • ",A'.�� Signature `v► ailtPhone (907)777-8323 Date 7/20/2015 7 7 h is- RBDM JUL 2 3 2015 Form 10-404 Revised 5/2015 Submit Original Only Anna Platform SCHEMATIC . AN-17A Well tion Date: 06/22/2015 Ililcorp Alaska,LLC CASING AND TUBING DETAIL API#50-733-20311-01 SIZE WT GRADE CONN ID TOP BTM (in) (lbs/ft) (in) (ft) (ft) 30 94 X-55 - - Surf 30"z1 1 t ALL 20 91.5 X-52 19.124 Surface 610 , 13-3/8 54.5,61, K-55&L-80 BTC 12.347 Surface 3,514 68,72 _ 20'Z 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 • 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 _ DWC/C HT 6.184 9,403 12,915 Tubing 13 3/8"Z Long String 2-7/8 6.4 L-80 EUE 2.441 Surface 9,223' 2-7/8 6.4 L-80 IBT SC 2.441 9,223' 10,017' Short String 2-7/8 6.4 L-80 EUE 2.441 Surface 9,197' 2-3/8 6.4 L-80 IBT SC 2.441 9,197' 10,017' XO IBT Item Description :ripOD Depth ( ) ( ) (ft) 9,220' RKB - - - 22" 1 Tubing Hanger 3 1/2"EUE Lift and Suspension 2.441 2.875 51' 2 B 2 XO 2 7/8"8Rnd EUE X 2 7/8"IBT SCC 2.441 2.875 9,223' 3 XO 2 7/8"IBT SCC X 2 7/8"EUE 2.441 2.875 10,015' 4 Kobe cavity 2 1/2" - 5.875 10,017' 5 "R"-Landing Nipple 2.188 3.680 10,023' 6 Ratcheting Mule Shoe 2.441 4.000 10,056' 7 CIBP 11,875' 8 Packer:7"26-32#Model"D"Permanent Pkr 3.250 5.810 11,900' 9,403' >< Concentric Packer Adapter 3.250 5.810 11,901' Seal Bore Extension:3.250"X 5' 3.250 4.250 11,902' 9 5/8" Tbg Adapter:2-7/8"EUE Box 2.810 4.990 11,906' 3 kN 9 "R"-Landing Nipple 2.188 3.669 11,915' 4 10 Sliding Sleeve 2 7/8","R" 2.188 3.190 12,055' Lt Pyrotechnic Delay Firing Head 3.125 12,077' 5 Blank Safety Spacer:4 1/2" = 4.500 12,078' 6 SPF SDP TCP Assembly:4.5"Top Shot 4.500 12,084' 6 6 SPF SDP TCP Assembly:4.5"Btm Shot 4.500 12,450' Lower Firing Adapter:4.5" - 3.125 12,451' Pyrotechnic Delay Firing Head - 3.125 12,453' Top of Short String Cement-_� tti ,: ,�cp RKB 11,845' - - - 7 _11111r-di A Tbg hanger - - 50' 8111 B XO 2 7/8"8rnd EUE X 2 3/8"IBT SCC 1.995 3.680 9,197' C XO 2 3/8"IBT SCC X 1.25 NPT 1.250 2.700 10,017' I 9 S-Sleeve LWR 12,055' 10 119 1 I Perforation Detail 69' i Zone Top Btm Top Btm Amt SPF Date Status (MD) (MD) (ND) (TVD) _ CSB 9,241' 9,248' 8,980' 8,986' 7' 5 6/18/2015 Open C5B 9,260' 9,279' 8,997' 9,014' 19' 5 6/18/2015 Open C7A 9,541' 9,554' 9,253' 9,264' 13' 5 6/18/2015 Open C7A 9,568' 9,580' 9,277' 9,288' 12' 5 6/18/2015 _ Open C7C 9,652' 9,669' 9,352' 9,367' 17' 5 _ 6/18/2015 Open C7C 9,678' 9,704' 9,374' 9,397' 26' 5 6/18/2015 Open C7E 9,758' 9,781' 9,444' 9,464' 23' 5 6/18/2015 Open C8B 9,919' 9,969' 9,581' 9,623' 50' 5 6/18/2015 Open C8C 10,013' 10,074' 9,659' _ 9,708' 61' _ 5 6/18/2015 _ Open C9B 10,420' 10,433' 9,976' 9,985' 13' 5 6/18/2015 Open C9C 10,580' 10,590' 10,091' 10,098' 10' 5 6/18/2015 Open C9C 10,634' _ 10,648' 10,129' 10,139' 14' 5 6/18/2015 Open C10 10,967' 10,972' 10,349' _ 10,352' 5' 5 6/18/2015 _ Open C11 11,440' 11,455' 10,596' 10,603' 15' 5 _ 6/18/2015 _ Open C11 11,469' 11,499' 10,609' 10,621' 30' 5 6/18/2015 _ Open Hemlock 11,969' 11,983' 11,224' 11,237' 14' 6 6/14/2015 Isolated 7 / `f.w `:i"%. Hemlock 12,047' 12,067' 11,299' _ 11,319' 20' 6 6/14/2015 Isolated Hemlock 12,084' 12,450' 11,335' 11,689' 366' 6 6/14/2015 Isolated PBTD=12,735'MD(11,050'TVD) Hemlock 12,450' 12,453' 11,689' 11,692' 3' 12 6/14/2015 Isolated Updated by:1LL07/20/15 Hilcorp Alaska, LLC Hikrp Alaska.LLC Well Operations Summary Well Name API Number Well Permit Number _Start Date End Date Granite Pt St 18742 17A 50-733-20311-01-00 213-049 6/10/2015 6/22/2015 Daily Operations: 06/10/15-Wednesday Bleed off tbg pressure f/783 psi to"0"w/150 bbls back to pits,getting back gas.Pooh w/E-line tbg punch.Rig down E-line. R/up hoses to production,pumped fluid out to ISO tank.Rigged up pump lines to pump down annulus and take returns to ISO tank.Weight up fluid in pits to 9.9 ppg.Held pre job meeting on circulating fluid.Pump tbg volume on long string side. Pump out ISO to production.Build 120 bbls 9.9 ppg KCL. Open S/S had 110 psi,reverse circ taking return f/S/S until 9.9 back at surface.Pump total of 83 bbls. Rig up on S/S to return to pits.Circ down L/S taking returns from the S/S,pump two tbg volumes total 260 bbls with 9.9 ppg back at surface. Monitor well for flow.SI tubing,open 9-5/8" 25 psi bled off to 0 psi.CSG static.Build 65 bbls to 9.9 ppg. R/d eline. Set BPV's both in long/short string.Remove flow lines on both long/short string. Remove rig floor and install handrails.R/d tree, pressure up both long/short SCSSV to 4500 psi and lock open.N/u riser and bops. R/u scaffolding around bops and remove bop lift plate. 06/11/15-Thursday R/u bell nipple,flow line to shakers,drip pan and h-beam and floor plates. M/u 2-7/8"&2-3/8"test joints into hgr.Fill stack,prepare to shell test. Shell test stack to 3000 psi.Have leak on x-overs into hgr.Pull test joints to surface and teflon same.M/u into hgr and .t4;6�J� shell test,good test. Start testing bops asper Sundry 250_psi Low,3000 psi High.Perform draw down Koomey test. Pull 2-way ,r checks.Install BPV's.R/u Weatherford Dual handling equipment. P/u to 122k and unseat dual hgr.Continue picking up to 170k and LS slack off to 140k several times.P/u to 195k p/u weight fell to 125k.Continue p/u to 156k free pipe weight.Pull dual hgr to floor. L/d hgrs and continue pooh with dual string 2-7/8"EUE tubing. 06/12/15-Friday Pooh 1/d 2-7/8"EUE 6.4#production tubing.L/S(85 jts)S/S(85 jts)total joints laid down 170 joints. Cont pooh I/d 2-7/8"EUE production tubing.3,314'left in hole with 261 joints out on both L/S&S/S.522 joints total ooh with 2-SCSSV's.Amount 1/d 8,602'. 06/13/15-Saturday Continue I/d 2-7/8"6.4 EUE dual string. Change out air cylinder on dual slips and change slip inserts on short string side slips and elevators to 2-3/8". Cont.pooh 1/d 2-7/8"6.4 IBT &2-3/8"4.6 IBT dual string tubing. Weatherford power pack broke down,change out power unit. Cont.pooh I/d 2-7/8"6.4 IBT &2-3/8"4.6 IBT dual string tubing,I/o Pump cavity,I/o 2-7/8 EUE tail pipe.Ooh with Seal Assembly,all completion string recovered. 11,906'recovered on L/S including 1-SCSSV,52-jts 2-7/8"IBT,289 Jts 2-7/8"EUE, Seal assembly,Pump Cavity.11,592'recovered on S/S including 1-SCSSV,78-jts 2-3/8"IBT,179 jts 2-7/8"EUE. R/u Weatherford dual equipment from rig floor.Clean and clear rig floor and pipe deck. Change out upper dual rams to 5"x 2-7/"VBR.Test 250 psi Low and 3000 psi High,Good Test.L/d test plug and install wear bushing. R/u eline and pressure test lubricator to 1000 psi,Good Test. Tih with 6.0 OD gauge ring and junk basket to 11,900'.Pooh,had overpull coming out of liner @ 9,400'. Ooh with gauge ring,found metal shaving and paraffin.Decided to rerun junk basket and gauge ring. 06/14/15-Sunday (� Continue tih with junk basket and 6.0 OD Gauge ring to 11,780'.Having trouble getting down pass.Pooh. Ooh.Left junk basket and gauge ring in well.Wait on fishing tools. M/u 4-1/2"skirted SB pulling tool,sprang jars and oil jars.Tih to 11,900'Pooh.Recovered junk basket. M/u 5.61 CIBP and tih to 11,875'ELM and set bridge plug.Pooh with setting tool. Ooh.M/u 5 x 30'bailer,mixed and fill w cmt.TIH to11,860'shoot bailer,pooh. Mix second batch of cmt.Tih to 11,845'shoot bailer,pooh. Ooh.L/d bailer and m/u bond 15 log tool string. Tih with bond log to 9,450'logged up to 2,500',Good Cmt.Pooh. R/d eline and repair bell nipple.Install drip pan,H- C' beam and floor plates.R/u tongs,r/d stabbing board. M/u BHA#1 6"Bit,X-over,X-over=6.51'with 3-1/2 PH-6 workstring to 2,484'. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 17A 50-733-20311-01-00 213-049 6/10/2015 6/22/2015 Daily Orations: 06/15/15-Monday Continue tih with 3-1/2"PH-6 out of the derrick. Continue tih with 3-1/2"PH-6 workstring tallying and drifting off of the pipe rack. Tagged cement 11,833'. L/d 1 joint and p/u 10'pup.R/u pump in sub. Start circ 6%KCL 9.9#complete surface to surface. Finish circ ,( 721 bbls 9.9#in/9.9#out.R/u and pressure test cement_to 1500Asi for-15 mins.Good Test. Pump remaining fluid out of pits into t rain for rent tanks and clean tank for diesel. Continue displacing well with diesel.63 bbls pumped @ 2.1 bpm at 1630 psi. Mud Pump (7.7 main drive chain(Quad-80)broke.Close in workstring with 1630 psi.Moncla trying to locate another chain. 06/16/15-Tuesday Service rig and clean rig and main deck while waiting on main drive chain for pump. Receive main drive chain.Install on mud pump and test.Everything good. Pressure up work string to 1600 psi,open floor valve 1630 on workstring.Continue displacing well with diesel @ 2.25 bpm @ 1833 psi. 6.8PPG diesel going in 6.8PPG coming out.Shut in well and monitor.904 bbls total pumped,0 psi on annulus and workstring.U-tubing up the tbg open annular.Continue circulating,6.8ppg in/6.8 ppg out. Pooh with 3-1/2"PH-6 workstring to 11,343(16 jtsl/d). 06/17/15-Wednesday Continue l/d 3-1/2"workstring 81 joints total. Continue pooh racking workstring in derrick. Ooh b/o bit and bit sub. Clean rig floor and Hold JSA meeting on running guns with Halliburton crew.Prepare rig floor. Tih with 4-5/8"39 gram Millennium 2 deep Pen. 5SPF 60 Phase TCP assembly=2,408'. Continue tih with 3-1/2"PH-6 workstring drifting from derrick to 5,397'. 06/18/15-Thursday Continue tih with 3-1/2"PH-6 workstring and perf guns. Install 25.17'of pups and std 148+9,130' top of gun assembly.P/u and rack ,(v back std 148 9,100'top of gun assembly.188k p/u weight,116k s/o weight. R/u eline. Pressure test Lubricator to 1000 psi,Good Test.TIH with 1-11/16"Gamma/CCL with 5'weight bar make correlation pass&send t/town,adjust log,find r/a marker 4.5'high. L/d 25.17'pups.Rih t/9,127'p/u t/9,096.8'with R/a marker.R/u a-line make correlation pass#2,verify on depth w/top shot @ 9,241'.Send t/town t/verify on depth, good. Well U-tubing,fill well 2 bbls to fill.Reverse circ 1 tubing volume @3 BPM,220 psi to balance well. Drop bar took(3mins 40 seconds)to fire guns,good indication at surface guns fired,open TIW well was on vac,took 16 BBLs t/fill hole. Pooh to above 7"liner @9,400'. R/u rev.CBU X2 @ 4 bpm,400 psi,shut down,monitor well,U-tubing,circulate 200 bbls t/bal.Losses while circ 5 BPH.Monitor well,static. Pooh 1/d 3 1/2"PH-6 workstring,well losing 1.5 bbls/hr. Clear pipe rack,m/u safety jt,prep t/l/d guns. 06/19/15-Friday Cont.l/d TCP assy.L/d 54. Back load&unload boat w/ISOs filled f/R4R tanks,pipe racks w/work string&3 gun baskets.Unload gun baskets. Cont.l/d guns,bleed trapped pressure as needed whilel/d, all shots fired. C/o handling eq,tih w/32 stands 3 1/2 PH-6 wk string. POOH L/d 62 jts 3 1/2 workstring,clean rig floor. Change out top VBR's to Dual Flex rams. M/U 2 3/8 t/j, pull wearbushing, install test plug. Test BOPE as per Hilcorp&AOGCC regulations.Test witness waived by AOGCC,Jim Regg @ 8:52 on 6-17-15. Tested w/2 7/8"&2 3/8 Ti's. Test dual rams w/both. Test 250 low,3000 high,all good. L/d tj, R/u dual handling equipment. 06/20/15-Saturday R/u dual handling equipment, stabbing board. M/u Indexing M/S,1-joint 2-7/8"EUE,R nipple,pup joint,Pump Cavity,dual joints. Tih with 2-7/8"6.4#IBT SC on Long String/2-3/8"4.6#IBT SC Short String. M/u X-over 2-7/8"IBT Pin x 2-7/8"EUE Box on Long String/2-3/8"IBT Pin x 2-7/8"EUE Box.Continue running dual 2-7/8"6.4#EUE Completion string t/9,449'. • Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 17A 50-733-20311-01-00 213-049 6/10/2015 6/22/2015 Daily Operations: 06/21/15-Sunday Cont.RIH w/2 7/8 dual completion t/10,033'. M/U DCB dual hanger's,w/landing jts,rih t/10,052',up wt 158k,do wt 108k. Drop standing valve in long string.R/u&bundle test tubing t/1500 f/15 min good.Bleed off& r/d test eq. M/u pup jts on both landing jts. P/u&remove slips.Land hanger's w/2 7/8 dual completion,ratcheting mule shoe,jt 2 7/8 EUE 8rd,R nipple,2 7/8 EUE pup,pump cavity,xo,26 jts 2 7/8 L-80 IBT tubing, xo,281 jts 2 7/8 eue 8 rd tubing w/1 pup jt,xo, hanger=L/S 10,058.36', xo,27 jts 2 3/8 L-80 IBT tubing,xo,280 jts 2 7/8 eue 8 rd tubing w/3 pup jt's,xo, hanger=S/S 10,021.12'. Run in 1/d pins,pack off hangers,good,b/o landing jts,set BPV's,break down test jts&landing jts. R/d dual handling eq,flush&blow down surface lines,r/d floor plates,H- beam,drip pan. R/d bell nipple,annular w/DSA,Double gate BOP,mud cross,single gate and riser. N/u tree,test void t/5000 good, test tree short string had leak on valve,repaired retest good. 06/22/15-Monday Test tree L/S t/5000 good.Turn well t/production. Clean&clear rig floor.R/d gas buster,G/B stand,circulating lines,m/t mud pits. Coil up electrical lines t/same&prep t/ship.Remove D/S stairs, front&rear curtain walls,upper wind walls,&clean same.R/d accumulator lines,disconnect remote panel.R/d service lines in sub-base.R/d lines in derrick,clean and organize for shipping. r s • „P 0F„T01, THE STATE Alaska Oil and Gas .e.p.A _ __.__7__.4„.=. _�� fALAs� Conservation Commission _:._____,__, 1 } =_-_-,-;:_-_-v_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OFALAS�P Fax 907.276.7542 www.aogcc.alaska.gov SCANNED JUN 0 5 2015 Dan Taylor L/p Operations Engineer Djj...__________.-----'.5— ° "[ "�Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Granite Point Field, Hemlock Undefined Oil Pool, Granite Point St 18742 17A Sundry Number: 315-263 Dear Mr. Taylor: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a164 Cathy P. Foerster Chair DATED this Z day of June, 2015 1 Encl. RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APR 3 9 2015 _ APPLICATION FOR SUNDRY APPROVALS D C72.(/. 22AAC 25280 1.Type of Request: Abandon CI Plug for Redrill❑ Perforate New Pod 0• Repair Well❑ ange�Gpproed Program El Suspend❑ Plug Perforations I] Perforate❑ Pull Tubing 0- lime Extension❑ ❑ Operations Shutdown Re-enter Susp.Well CICICIAlter Casing CI Other Run Dual String Jet Pump D Completion - 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory p Development E • 213-049 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20311-01 , 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool?0�20 AAC 25.055 r Will planned perforations require a spacing exception? Yes Lb No I. Granite Point St 18742 17A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 Granite Point Field/Hemlock Undefined Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND ):8 Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ►iaq 13,670 4-2;888 12,735 11,050 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 610' 20" 610' 609' 2,110 psi 520 psi Surface 3,514' 13-3/8" 3,514' 3,445' 2,730 psi 1,130 psi Intermediate Production 10,483' 9-5/8" 10,483' 9,789' 6,820 psi 3,330 psi Liner 3,512' 7" 12,915' 12,138' 11,220 psi 8,530 psi Perforation Depth MD(ft). Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" &2-3/8"Dual 6.4#/L-80 11,907'&11,593' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Model D Packer and SSSV r Pkr 11,900'(MD)11,157'(ND)/360'(MD)360'(ND)• 12.Attachments: Description Summary of Proposal Cl 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic Cl Development CI. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/11/2015 Oil Cl. Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ El GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and corn/• o the best of my knowledge. Contact Dan Taylor -�`) Email dtaylor(a)hilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature , Phone (90)777-8420 Date 4/30/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3'J Plug Integrity ❑ BOP Test IVMechanical Integrity Test ❑ Location Clearance CIOther: 3t. p 5L. SOP s r (M.st 7 1-370i,s L, X. <<tvi, _ FLou, rr s-/- re-1 (-4-5.--1-e-42 Co ?4,53 1ssc r�/Vac2//s Spacing Exception Required? Yes El No ❑ Subsequent Form Required: /Q— 416 N APPROVED BY Approved by: ‘4147 P COMMISSIONER THE COMMISSION Date: Z -./.5"- Submit S 17/13- COMMISSIONER s Zy.tr Submft Form and Form 10-403(Revised 10/2012) Approved application Is vali r approval. Attachm nts in Duplicate , 1,217 (9 RBDMSc \\ JUN - 3 2015 11 Well Prognosis Well: An-17A llilcorp Alaska.LL: Date: 04/29/15 Well Name: GRANITE PT ST 18742#17A API Number: 50-733-20311-01-01 Current Status: Oil Producer Leg: 2 Estimated Start Date: May 11, 2015 Rig: Moncla 301 Reg. Approval Reqd? N/A Date Reg. Approval Rec: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 213-049 First Call Engineer: Trudi Hallett Office: 907-777-8323 Cell: 907-301-6657 Second Call Engineer: Dan Taylor Office: 907-777-8319 Cell: 907-947-8051 AFE Number: Current BHP: -6,000 psi @ 10,660 ft TVD 0.56 psi/ft, (10.8ppg) pressure build up 5/22/2014 Max. Expected BHP: -6,000 psi @ 10,660 ft TVD 0.56 psi/ft, (10.8ppg) pressure build up 5/22/2014 Max. Anticipated SP: -1,370 psi Using 8.35ppg fluid to 10,660ft TVD Brief Well Summary ) �- 04-" ee(� ( kIA., -2.........„ ) it,2-i r s` z gffP An-17A was brought on-line in February 2014. It averages 15bwpd and no oil. Our procedure includes plugging back the Hemlock perforations and recompleting the well in the Tyonek sands with a dual string jet pump completion. Last casing test performed January 2014 (2,600psi, 30min). Procedure 1. Shut in well and record stable shut in tubing pressure. 2. Rig up slick line. a. Run in hole and set RX plug in lower R nipple (11,914ft MD). b. Bleed off tubing pressure. c. Run in hole and shift upper sliding sleeve open (12,055ft MD). 3. Circulate 6% down long string taking returns up casing. a. Repeat on short string. u �J>r..+`� **Work over fluid 6% KCL, 8.65ppg** , .KW r 4. Ensure well is dead. 5. Set BPV. 6. Nipple down tree/ Nipple up BOPE. a. Function test BOPE (notify AOGCC of test 48hrs prior to expected test). 7. Test BOPE: a. Test BOPE 250psi low and 3,000psi high and chart. 8. Remove BPVs. 9. Pull hanger(previous 200klbs). Pull completion out of snap latch (pervious 235k1bs). Pull out of seals (previous 220klbs). 10. Pull dual completion to SCSSSV's and lay down (LS OD 4.6in, SS OD 4.59in, Passing Total = 9.16in). 11. Rig up e-line on short string. a. Run in hole to cut 2-3/8in tubing at +/-11,580ft1 12. Pull out of hole with short string laying down singles. / 13. Pull out of hole with long string. 14. Rig up e-line. a. Run in hole with 7in CIBP and set at +/-11,875ft. v b. Run in hole with -30ft, -5in bailer placing cement to cover 30ft over CIBP (AOGCC 20 AAC 25.112. Well Plugging requirements, Sec (c).(1).(A)). c. Run in hole with CBL to identify top and quality of cement on 9-5/8in casing. ,,, 15. Pick up and run in hole with tubing conveyed perforating guns spacing out and shoot the following i---- intervals: kik ? ` �e > IS • II Well Prognosis • Well: An-17A llilcorp Alaska.Ll: Date:04/29/15 Zone . TopMD BtmMD TopTVD , BtmTVD Amt C5B 9,241 9,248 8,980 8,986 7 C5B 9,260 9,279 8,997 9,014 19 C7A 9,541 9,554 9,253 9,264 13 C7A 9,568 9,580 9,277 9,288 12 C7C 9,652 9,669 _ 9,352 9,367 17 C7C 9,678 9,704 9,374 9,397 26 C7E 9,758 9,781 9,444 9,464 23 C8B 9,919 9,969 9,581 9,623 50 C8C 10,013 10,074 9,659 9,708 61 C9B 10,420 10,433 _ 9,976 9,985 13 C9C 10,580 10,590 10,091 10,098 10 C9C 10,634 10,648 10,129 10,139 14 C10 10,967 10,972 10,349 10,352 5 C11 11,440 11,455 _ 10,596 10,603 15 C11 11,469 11,499 10,609 10,621 30 16. Pick up and run in hole with ratcheting mule shoe, XN nipple, 2.5in MVSR jet pump BHA, and dual strings setting BHA at +/-10,000ft MD. 17. Land hanger. 18. Set BPVs and test. 19. Nipple down BOP, nipple up tree and test. 20. Turn well over to production. 21. Complete 'No Flow' test in accordance with AOGCC regulations (20 AAC 25.265. Well safety valve systems, section.h). Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. Current/ Proposed Wellhead Diagram (same) 4. BOP Stack Anna Platform Schematic well No. AN-17A . II Completion Date: 2/22/2014 Hikorp Alaska,LLC CASING AND TUBING DETAIL API #50-733-20311-01 SIZE WT GRADE CONN ID TOP BIM (in) (lbs/ft) (in) (ft) (ft) 1 J A30 94 X-55 Surf - 20 91.5 X-52 19.124 Surface 610 2 B 13 318 54.5, K-55&L-80 BTC 12.347 DWC/C HT 8.681 Surface 3,514 61,68, 72 9 5/8 47 L-80 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 30" Tubing Long String • XO IBT 2-7/8 6.4 L-80 EUE 2.441 Surface 9,220 20„2 9,220' , 2-7/8 6.4 L-80 IBT SC 2.441 9,9222 11,907 22' Short String 3 c , 2-7/8 6.4 _ L-80 EUE 2.441 Surface 9,224 133/8"L 2-3/8 6.4 L-80 IBT SC 2.441 9,224 11,593 Item Description ID OD Length Depth RKB (in) (i- (51ft) (ft) - 1 Tubing Hanger 3 1/2" EUE Lift and Suspension 2.441 2.875 0.8 51 9,403' > >< 2 SCSSSV 3-1/2” Ser#625572, "X' Profile @ 2.81" 2.810 5.170 4.5 360 L \ 3 XO 2 7/8" 8Rnd EUE X 2 7/8" IBT SCC 2.441 3.640 1.6 9,220 95/8" 4 XO 2 7/8" IBT SCC X 2 7/8" EUE 2.441 3.250 2.4 11,593 4 j1) JP BHA 5 Kobe cavity 21/2" 2.250 5.562 3.3 11,595 5 11,595' 6 "R"-Landing Nipple 2.188 3.669 1.7 11,598 67" 7 _Sliding Sleeve 2 7/8" BTS-8, Non-Elas, "R" 2.188 3.190 5.3 11,901 Snap Latch locator 2.441 4.750 0.7 11,899 6 R Seal Assembly 2.441 3.230 5.4 11,900 Racheting Mule Shoe 2.375 3.230 1.5 11,905 8 Packer: 7"26-32#Model "D" Permanent Pkr 3.250 5.810 1.8 11,900 Concentric Packer Adapter 3.250 5.810 0.5 11,901 9 _Seal Bore Extention: 3.250"X 5' 3.250 4.250 4.5 11,902 Tbg Adapter:2-7/8" EUE Box 2.810 4.990 0.6 11,906 10 2.188 3.669. S-sleeve UPR .tom' L.A " 11 Sliding Sleeve 217/8", "R" 2.188 3.190 1.1 11,915 ({ Landing pp 11,901, 4.1 12,055 69' 7 DO Pyrotechnic Delay Firing Head - 3.125 1.3 12,077 Blank Safety Spacer: 4 1/2" 4.500 6.0, 12,078 8 6 SPF SDP TCP Assembly: 4.5"Top Shot - 4.500 366.0 12,084 9 6 SPF SDP TCP Assembly: 4.5" Btm Shot - 4.500 12,450 00.1r- Lower Firing Adapter: 4.5" - 3.125 0.9, 12,451 10 Pyrotechnic Delay Firing Head - 3.125 2.3 12,453 S-Sleeve LWR Short String 12,055' 11 MO RKB - - 51.5 - 69" = A -flog hanger - - 0.9 50 • B SCSSSV 2-7/8" Ser#628249, "X' Profile @ 2.81" 2.310 4.590 4.1 371 • • C XO 2 7/8" 8rnd EUE X 2 3/8" IBT SCC 1.995 3.700 1.7 9,226 a D XO 2 3/8" IBT SCC X 1.25 NPT 1.250 2.700 1.9 11,591 • 1r — I • I T Perforation Details • Top Btm Top Btm • - Date Zone (MD) (MD) (ND) (TVD) Amt SPF • • • 5/10/2014 Hemlock 11,969' 11,983' 11,224' 11,237' 14' 6 •• 5/10/2014 Hemlock 12,047' 12,067' 11,299' 11,319' 20' 6 •I . 2/21/2014 Hemlock 12,084' 12,450' 11,335' 11,689' 366' 6 = 1/16/2014 Hemlock 12,450' 12,453' 11,689' 11,692' 3' 12 PBTD=12,735'MD(11,050'TVD) Updated by:1LL 05/28/14 Anna Platform II PROPOSED Well No. AN-17A Completion Date: Future Hilcorp Alaska,LLC CASING AND TUBING DETAIL API #50-733-20311-01 SIZE WT GRADE CONN ID TOP BTM (in) (lbs/ft) (in) (ft) (ft) 1L A 30 94 X-55 - - Surf - 30" 20 91.5 X-52 19.124 Surface 610 13-3/8 54.5,61, K-55&L-80 BTC 12.347 Surface 3,514 68,72 20'Z 9-5/8 47 L-80 DWC/C HT 8.681 Surface 8,720 9-5/8 47 P-110 DWC/C HT 8.681 8,720 10,483 7 29 P-110 DWC/C HT 6.184 9,403 12,915 Tubing 13 3/8"A , Long String 2-7/8 6.4 L-80 EUI 2.441 Surface ±9,220 2-7/8 6.4 L-80 IBT SC 2.441 ±9,922 ±9,998 Short String 2-7/8 6 4 L-80 EUE 2.441 Surface ±9,226 2-3/8 6.4 L-80 IBT SC 2.441 ±9,228 ±10,000 Xo IBT Item Description ID OD Length Depth 9,220' (in) (in) (ft) (ft) 22' RKB - - 51.46 - 2 1-11-1 B 1 Tubing Hanger 3 1/2"EUE Lift and Suspension 2.441 2.875 0.8 51 2 XO 2 7/8"8Rnd EUE X 2 7/8"IBT SCC 2.441 3.640 1.6 ±9,220 3 XO 2 7/8"IBT SCC X 2 7/8"EUE 2.441 3.250 2.4 ±9,998 4 Kobe cavity 2 1/2" 2.250 5.562 3.3 ±10,000 - 5 "R"-Landing Nipple 2.188 3.669 1.7 ±10,030 T_ 6 WLEG ±10,060 - 7 CIBP ±11,875 � 8 Packer:7"26-32#Model"D"Permanent Pkr 3.250 5.810 1.8 11,900 / 9,403' X /� Concentric Packer Adapter 3.250 5.810 0.5 11,901 Seal Bore Extension:3.250"X 5' 3.250 4.250 4.5 11,902 9 5/8 3 Tb Ada ter:2-7/8"EUE Box 2.810 4.990 0.6 11,906 i g P 4 9 RX Plug ±11,914 10 "R"-Landing Nipple 2.188 3.669 1.6 11,915 A 11 Sliding Sleeve 2 7/8","R" 2.188 3.190 4.1 12,055 5 R Pyrotechnic Delay Firing Head - 3.125 1.3 12,077 6 Blank Safety Spacer:4 1/2" - 4.500 6.0 12,078 6 SPF SDP TCP Assembly:4.5"Top Shot - 4.500 366.0 12,084 6 SPF SDP TCP Assembly:4.5"Btm Shot - 4.500 12,450 Top of Lower Firing Adapter:4.5" - 3.125 0.9 12,451 Cement-_, ,t, Pyrotechnic Delay Firing Head - 3.125 2.3 12,453 ±11,845' a G 06P Short String 7 RKB - - 51.5 - 8 A Tbg hanger - - 0.9 50 I B XO 2 7/8"8rnd EUE X 2 3/8"IBT SCC 1.995 3.700 i. ±9,226 9 C XO 2 3/8"IBT SCC X 1.25 NPT 1.250 2.700 1.9 ±9,998 10 R 5-Sleeve LWR - Perforation Details 12,055' 11 Top Btm Top Btm 69" - Date Zone Amt SPF (MD) (MD) (TVD) (TVD) Future CSB ±9,241 ±9,248 ±8,980 ±8,986 ±7 Future C56 ±9,260 ±9,279 ±8,997 ±9,014 ±19 s. Future C7A ±9,541 ±9,554 ±9,253 ±9,264 ±13 Future C7A ±9,568 ±9,580 ±9,277 ±9,288 ±12 - Future C7C ±9,652 ±9,669 ±9,352 ±9,367 ±17 Future C7C ±9,678 ±9,704 ±9,374 ±9,397 ±26 s Future C7E ±9,758 ±9,781 ±9,444 ±9,464 ±23 - Future C8B ±9,919 ±9,969 ±9,581 ±9,623 ±50 Future C8C ±10,013 ±10,074 ±9,659 ±9,708 ±61 Future C9B ±10,420 ±10,433 ±9,976 ±9,985 ±13 Future C9C ±10,580 ±10,590 ±10,091 ±10,098 ±10 Future C9C ±10,634 ±10,648 ±10,129 ±10,139 ±14 - Future C10 ±10,967 ±10,972 ±10,349 ±10,352 ±5 Future C11 ±11,440 ±11,455 ±10,596 ±10,603 ±15 s Future C11 ±11,469 ±11,499 ±10,609 ±10,621 ±30 5/10/2014 Hemlock 11,969' 11,983' 11,224' 11,237' 14' 6 5/10/2014 Hemlock 12,047' 12,067' 11,299' 11,319' 20' 6 7--A . 2/21/2014 Hemlock 12,084' 12,450' 11,335' 11,689' 366' 6 PBTD= 12,735'MD(11,050'TVD) 1/16/2014 Hemlock 12,450' 12,453' 11,689' 11,692' 3' 12 Updated by:.ILL 04/30/15 • Anna Platform An-17A Harm". 1.In.ku.1.1.(. An-17A Tubing hanger,CIW-DCB, 20X133/8X95/8X27/8X 11X3'EUElift X334IBT 2 7/8 susp,w/'A non cont control line ports,5 3/64 centers 0Th r .0 I II al_ r Tree assy,dual block,CIW-F, 1 115MX31/85MX 3 1/8 5M,prepped on 5 3/64 center,3"CIW seal 1: r.;,--..,--ittpockets,'A npt control line exits n imu r�� N.---07 X2 control lines ._ii305 .�. - ' Tubing head,CIW-DCB, 13 5/8 3M X 11 5M,w/2- "1:/11— I •J- 'y 2 1/16 5M SSO,X-bottom #xea' pfep = '1:-Cil �� ilI i o , 101 lia. z' = r lilt. DSA,13 5/8 3M X 13 5/8 3M = ainrg ,.- w/full set of lockpins for packoff on mandrel hanger Casing spool,CIW-WF, I — 21'/.2MX135/83M, III 151 w/2-2 1/16 5M EFO, ' Ai EL , l4) X bottom prep Ilip MilI��°. ��Iii O -Il li ' I . III I . ISI Casing head,CIW-WF, 1. I, 21''/.2MXSOW,w/ Ali 2-2 1/16 2M EFO , ` f S MI I ■11I1O 1'j1•-i. 1 :so 1 II • Anna Platform • MoB 03/16/2015nclaOP Hilrnrp,Uarkr,1.IA. tuitutt iftltt, 4 lit Iii 1111111/1 r '1 I I S ow-u I i i I ; rap Choke and 1011 va'ves 31/8 5M 1 I 11'111"111 r l- F.1��I (�F 2.26 1' /4) TO 0 1-I�� iii II lil;il Ilti ".44I Q II 'II I. 2.83' .. ,.. . I i '.111ii iii 41.111 I!I 1111!1 Ill III Riser 135/S SM 55 X135/85M ES 11.UU• 111 I11 111111 III III III III Ii1.111 2,Oo' Spacer spool 135/85M 113 5/8 5M Ill !ll 111 lil 111 Air 2.15 svaa..pam I11 111111 III 111 135/85M FE X 115M III inn Moncla 301 BOP Test Procedure Hileorp Alaska.LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing(test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 2) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure Moncla 301 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 3) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 4) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage, Alaska 99501 Re: THE APPLICATION OF Hilcorp ) Docket No. CO-15-005 Alaska, LLC to re-complete the Granite ) Conservation Order No. 76.33 Point State 18742-17A development oil ) well within 1,000 feet of, and within the ) Granite Point State 18742-17A same governmental quarter section as, ) Granite Point Field wells that are, or may be capable of, ) Middle Kenai Oil Pool producing from the same pool. ) May 26, 2015 IT APPEARING THAT: By a letter received May 11, 2015, Hilcorp Alaska, LLC (Hilcorp) requests an order allowing re- completion of the Granite Point State 18742-17A development oil well within 1,000 feet of, and within the same governmental quarter section as, wells that are, or may be capable of, producing from the same pool. FINDINGS: 1. Hilcorp is the operator of the Granite Point Field (GPF) and is the operator of the GPF State (ST) 18742-17A development oil well that is located on the west side of the Cook Inlet, Kenai Peninsula Borough, Alaska. 2. The GPF ST 18742-17A well is an offshore, deviated development oil well with a surface location of 798 feet from the north line and 596 feet from the east line of Section 12, Township 10 North, Range 12 West, Seward Meridian (S.M.). The bottom hole location is 898 feet from the south line and 1,994 feet from the west line of Section 12, Township 10 North, Range 12 West, S.M. 3. The GPF ST 18742-17A well is located entirely within State of Alaska Oil and Gas Lease ADL 18742. 4. The GPF ST 18742-17A well is currently completed in the undefined Hemlock Oil Pool. This well has been unsuccessful as a Hemlock producer. I lilcorp proposes to plug the well back and re-complete it in the Middle Kenai Oil Pool within an area governed by Conservation Order No. 76. 5. The GPF ST 18742-17A will be the fourth well within the southeast quarter of Section 12 capable of producing from the Middle Kenai Oil Pool. 6. The GPF ST 18742-17A will be within 1,000 feet to the GPF ST 18742-21, 23RD and 09 development wells that produce or are capable of producing from the Middle Kenai Oil Pool. 7. Conservation Order 76, Rule 2. Spacing provides a. not more than two completed wells shall be allowed in any governmental quarter section; and b. no pay opened to the well bore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well drilling to or capable of producing from the same pool. 8. Conservation Order 76, Rule 7. Administrative Approval specifies in part that the Alaska Oil and Gas Conservation Commission (AOGCC) "...may authorize the conversion or • CO 76.33 May 26,2015 Page 2 of 2 drilling of any well at any location..,reasonably designed to further the purposes of the project." 9. The re-completion of GPF S'I' 18742-17A is designed to maximize recovery from the Middle Kenai Oil Pool at Granite Point Field by accessing un-drained reserves in oil reservoirs that cannot be reached by wells conforming to applicable spacing restrictions. 10. In conformance to Rule 7 of Conservation Order No. 76, Hilcorp gave notice of this request to all potentially affected landowners, owners and operators—those within 1,000- foot radius of the GPF ST 18742-17A well—the State of Alaska, Department of Natural Resources (DNR) and Hilcorp Alaska, LLC. Hilcorp sent notice of its application to the DNR. DNR received the notification on May 11, 2015. The AOGCC received no objection or comment regarding Hilcorp's request. CONCLUSIONS: 1. An exception to the well spacing provisions of Rule 2, CO 76 is necessary to allow re- completion of the GPF development oil well in order to maximize recovery of reserves. 2. A spacing exception to allow re-completion of the GPF ST 18742-17A development oil well is consistent with sound engineering and geoscience principles and will not result in waste or jeopardize correlative rights of adjoining or nearby owners. NOW THEREFORE IT IS ORDERED: Hilcorp's May 11, 2015 application for an order granting an exception to the well spacing requirements of 20 AAC 25.055(a)(3) to allow re-completion of the GPF ST 18742-17A development oil well is APPROVED. Hilcorp may proceed as long as it complies with the terms of the applicable Alaska laws, and all other legal requirements. 80,011,.4A,4 DONE at Anchorage, Alaska and dated May 26, 2015. n Cathy . Foerster Daniel T. Seamount, Jr. .c-' ;{ ; Chair, Commissioner Commissioner �i7t'v C RECONSIDERATION AND APPEAL NOTICE As provided in AS 31 05 080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may tile with the AOGCC an application for reconsideration of the matter determined by it If the notice was mailed,then the period of time shall be 23 days An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous the AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is tiled Failure to act on it within IO-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. I'he appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by Inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed If the AOGCC grants an application for reconsideration, this order or decision does not become final Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST he tiled within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. in computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period, the last day of the period is included,unless it falls on a weekend or slate holiday,in which event the period runs until 5 00 p In.on the next day that does not fall on a weekend or state holiday. Bettis, Patricia K (DOA) From: Judy Stanek <jstanek@hilcorp.com> Sent: Thursday, May 07, 2015 8:35 AM To: Bettis, Patricia K(DOA); Smith, Kyle S (DNR) Cc: Daniel Taylor; Jacob Dunston; Trudi Hallett; David Duffy Subject: Spacing Exception - Granite Pt St 18742 17A Attachments: GP AN-17A Spacing Except Application 5-2015.pdf Patricia, Kyle, Hilcorp as Operator of the Granite Point Unit has requested the Commission take administrative action to approve a spacing exception for the Granite Pt St 18742 17A well. Attached is a copy of the spacing exception application mailed today to Cathy Foerster, Chair of the Commission. The State is the only affected party. A copy was also mailed to Corrie Feige, Director of the Division of Oil and Gas. If you have questions please let me know. Thanks, Judy Judy Stanek,CPL Landman Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Ph: 907.777.8341 jstanek@hilcorp.com 1 Hilcorp Alaska,LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 May 7,2015 Phone:907-777-8341 Fax:907-777-8580 jstanek@hilcorp.com Cathy P.Foerster,Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 IIAnchorage,AK 99501 RE APPLICATION FOR SPACING EXCEPTION Granite Point State 18742 17A Well Dear Ms.Foerster: Pursuant to Rule 7 of Conservation Order 76,Hilcorp Alaska,LLC("Hilcorp"),as Operator of the Granite Point Unit,hereby requests the Alaska Oil and Gas Conservation Commission("AOGCC")to take administrative action to approve a spacing exception required to re-complete the Granite Point State 18742 17A well("AN-17A"),in Middle Kenai Oil Pool. AOGCC submitted the Permit to Drill AN-17A on March 19,2013. AOGCC approved the Permit to Drill on April 25,2013. Subsequently,this well was drilled and completed in the Granite Point Undefined Hemlock Oil Pool. To date,this well has been unsuccessful and it is necessary to plug- back and abandon the Hemlock perforations and recomplete the well up-hole in the Granite Point Middle Kenai Oil Pool. The anticipated productive interval and location of the Middle Kenai Oil Pool in the wellbore of AN- 17 is depicted on the attached plat,Exhibit A,and is further indicated as follows below: Surface Location: - State Lease ADL 18742 - 798' FNI., 596' FEL - Section 12,T1ON-R12W SM Top of the Middle Kenai Producing Interval: - State Lease ADL 18742 - 256' FEL, 2702' FSL - Section 12,T1ON-R12W SM Bottom of the Middle Kenai Producing Interval - State Lease ADL 18742 - 3044' FWL, 1380' FSL - Section 12,T10N-R12W SM • Granite Pt St 18742 17A Well Spacing Exception May 5,2015 Page 2 of 2 Bottom Hole Location - State Lease ADL 18742 898' FSL, 1,994'FWL - Section 12,T10N-R12W SM Well spacing within the Granite Point Middle Kenai Oil Pool is governed by Rule 2 of Conservation Order 76: Rule 2. Spacing; (a) Not more than two completed wells shall be allowed in any governmental quarter section. (b) No pay opened to the wellbore shall be nearer than 500 feet to any property line nor near that 1,000 feet to any well drilling to or capable of producing from the same This spacing exception is necessary because the proposed recompletion of AN-17A will be the fourth (4th)well within the southeast quarter of Section 12 capable of producing the Middle Kenai Pool. Also,the AN-17A will be less than 1,000 feet to the AN-21,AN-23RD and the AN-09 wells as shown on Exhibit A. However,the proposed perforation will target un-drained Middle Kenai reserves that cannot be reached by existing wells conforming to applicable spacing restrictions. Hilcorp is the sole operator of the Granite Point Unit/Field. The State of Alaska is the sole landowner. There are no other owners or operators affected by this proposed application. As such, correlative rights of all affected owners, landowners and operators will be protected by exception approval. It is requested that the Commission approve,by Administrative Approval,pursuant to Rule 2 of Conservation Order No. 76,an exception to the spacing for re-completing the AN-I 7A well. If you require additional information or would like to have a technical meeting regarding the AN-17A well,please contact Mr. Dan Taylor,Reservoir Engineer,at 907-777-8319 or you may contact the undersigned at 907-777-8341. Sincerely, Y Judy Stanek Landman cc: Corrie Feige,Director,Division of Oil and Gas,DNR(hardcopy) Kyle Smith,Unit Manager,Division of Oil and Gas(via email) Patricia Bettis, Senior Petroleum Geologist,AOGCC(via email) a C h 0 N N0 < 00r•-• Q U 4 ' 4-, a W L) ° Z 4A •O , +r C Q W _ ro .C) < — CD a) 04 c ( ea S I . j o 0 to i----------"---,•-•., i — ,11r__---i------ ' ----- tilik- j - .4- / I _ ...).,..,..N, _ __ . .._.... ..._. _.\.___ 4 w , o i . = o , , - • u.,S I. I. , N * ! T — 1.\‘\ < air I to a Z Q iv (,_ .. _i_ ,_ 1 : _ 1611101 S. , al _it_ ' z z I Z 1 1 �_ 1 ; I 0 a r‘ , t_ I Zr r+ po c o J v n ' a Z , N N ` 4 .C74 O h Q G N N h g s 1 a • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, May 04, 2015 10:57 AM To: dtaylor@hilcorp.com Subject: Granite Point St 18742 17A (PTD 213-049): Sundry Application Good morning Dan, CO 76, Rule 2 states that not more than two completed wells shall be allowed in an government quarter section; and no pay opened to the wellbore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any wells drilling to or capable of producing from the same pool. Please provide a spider map for Granite Pt St 18742 17A that shows the proposed perforation intervals within the Middle Kenai Oil Pool and the perforation intervals within the Middle Kenai Oil Pool for the surrounding wells. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Anna 17A Granite Point Field – Hemlock Oil Pool Offshore Cook Inlet – Waters of the United States Kenai Borough, Alaska November 2, 2013 – January 2, 2014 Provided by: Approved by: Jacob Dunston Compiled by: James Foradas Greg Hammond Josh Dubowski Dy l a n M u l l e r Distribution Date: 3/24/2014 Anna 17A 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3 1.1 Equipment Summary ...................................................................................................................... 3 1.2 Crew................................................................................................................................................ 3 2 GENERAL WELL DETAILS ................................................................................................................... 4 2.1 Well Objectives ............................................................................................................................... 4 2.2 Slot Recovery Operations and Milling of Cement Plug of existing wellbore of Anna 17 ................. 4 2.3 Kickoff of Anna 17A ........................................................................................................................ 4 2.4 Well Resume .................................................................................................................................. 6 2.5 Hole Data ........................................................................................................................................ 7 2.6 Daily Activity Summary ................................................................................................................... 7 3 GEOLOGICAL DATA ........................................................................................................................... 14 3.1 Lithostratigraphy ........................................................................................................................... 14 3.2 Lithologic Details ........................................................................................................................... 17 3.3 Sampling Program ........................................................................................................................ 33 4 DRILLING DATA .................................................................................................................................. 34 4.1 Surveys ......................................................................................................................................... 34 4.2 Bit Record ..................................................................................................................................... 38 4.3 Mud Record .................................................................................................................................. 39 4.4 Drilling Progress Chart .................................................................................................................. 41 5 SHOW REPORTS ............................................................................................................................... 42 6 DAILY DRILLING REPORTS ............................................................................................................... 43 Enclosures: 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD Anna 17A 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computer – Driller’s Monitor Rigwatch Remote Computer -- Pit Monitor Rigwatch Remote Computer -- Company Man Rigwatch Master (RWM) Computer – Night Company Man Computer -- Company Man Computer – Directional Driller Rigwatch Remote Computer – Tool Pusher Rigwatch Remote Computer – Mud Engineer Rigwatch Remote Computer – MWD Rigwatch Remote Computers – Mudloggers (3) RigWatch Master, DML, RigWatch Remote, WITS Feed from Pason Ditch gas QGM gas trap; Flame ionization total gas & chromatography. Hook Load /Weight on bit Canrig sensor Mud Flow In Derived from Strokes/Minute and Pump Output Mud Flow Out Canrig sensor Pit Volumes, Pit Gain/Loss Canrig sensors Pump Pressure Canrig sensor Pump Stroke Counters (2) Canrig sensor Rate of Penetration Derived from block height sensor RPM Canrig sensor Torque Canrig sensor WITS—To/From Schlumberger MWD Via Serial port from Mudlogger Rigwatch Remote 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML066 Mud Loggers Years1 Days2 Sample Catchers Years Days2 Technician Days2 James Foradas 6 44 Dean Kekaualua 7 7 Steve Forrest 4 Greg Hammond 3 27 Dylan Muller 4 11/2 Josh Dubowski 6 12/4 Dickey Hudgins 3 12/16 Dylan Muller 4 11/2 Ben Calo 1 12/14 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. Anna 17A 4 2 GENERAL WELL DETAILS 2.1 Well Objectives Anna 17A is a side track of an existing well to create a deviated development well to 13670' MD/11282' TVD to reserves from the Hemlock sand, up dip and along strike with current Hemlock producers. Integrated subsurface and 3-D geological interpretations, in conjunction with subsurface and previous production data indicates that oil reserves remain the Hemlock sand at GPF. Two down dip wells have successfully completed the Hemlock at GPF with each recovering over 1 MMBO. These reserves are booked and not recoverable in existing wellbores. Casing will need to be set just above the top of the Hemlock at approximately 11500'. This well is a hockey stick style plan with a max inclination of 63 degrees with build no greater than 3 degree per 100 and has an azimuth change of up to 9 degrees per 100' just after the kick off point. This sidetrack will kickoff from an existing cased well Anna 17, which was last utilized as a water injector. In 1998 communication between the 3.5" tubing and 9.625" casing was observed in Anna 17, and an unsuccessful attempt was made to get an MIT of the wellbore below 1558' MD. This was interpreted as likely resulting from leaking of the tubing and or the packer/seal assembly that put the tubing ID in direct communication with the 3.5” x 9.625” annulus. Hilcorp Alaska LLC Anna 17A kicked off at a depth of 3530 MD’ at 1016 hours on 9 November 2013 at the conclusion of slot recovery operations, summarized below. This well is a “re-drill” of the existing Anna 17 wellbore to the KOP of 2530 and is considered a sidetrack below his depth to TD. As detailed in the well plan, when completed the Anna17A will be the only Hemlock Pool well capable of producing the Southeast Quarter of Sec. 12, T10N, R12W, SM, AK. 2.2 Slot Recovery Operations and Milling of Cement Plug of existing wellbore of Anna 17 Prior to drilling this sidetrack (Anna 17A) a slot recovery operation killed the parent well (Anna 17). The 3.5" tubing was pulled and Anna 17 was plugged and abandoned across the perforated interval and CIBP 3664' MD. The 9.625" casing in Anna 17 was pulled to a depth of 3614' MD and a kickoff plug was balanced from 3664' to 3314' MD. Drilling of the cement kickoff plug mill window in Anna 17 commenced at 0810 hours on 8 November 2013 when cement was tagged at a depth of 3198' MD. At that time Canrig commenced full service logging of Anna 17A collecting spot samples of cement cuttings as directed by operations. Drilling to 3320’ MD proceeded without any problems, generating 107 units total gas. Between 3320’ and 3349’ MD returns of cement mixed with polymer clogged the shakers and possum belly temporarily. Circulating and conditioning of mud to remove polymer from the system and subsequently washing down from 3349 to 3368’ MD returned a maximum of 115 units of total gas; and subsequent washing down returned a maximum of 228 units total gas. Gas chromatography supported the conclusion that the gas was generated from drilling of cement contaminated with polymer and other mud additives; not any leaking of the casing or plug. This interpretation was based on very low (less than 400ppm) C1-C5 concentrations detected by Canrig’s chromatograph out of the total combustible gas volume (45,600 ppm maximum) detected by Canrig’s Total Hydrocarbon Analyzer. 2.3 Kickoff of Anna 17A Kickoff of Anna 17A began with time drilling out of cement into formation. This part of the project started with time drilling on 9 November at 1016 hours, at a kickoff depth of 3530’ MD. Anna 17A 5 During the time drilling Canrig collected and analyzed cuttings samples (see below). Collection of the spot samples began at a depth of 3540’ MD at the request of the Directional Driller. Samples were collected using a 100 mesh screen, washed and analyzed under 35x binocular microscope using standard cuttings analysis techniques. None of these samples were collected. The composition of each spot sample with respect to percentages of cement and formation cuttings were recorded and communicated to operations personnel. Reaction to Phenolphthalein indicator solution used to assist in resolving cement from formation. Mud additives observed in the spot samples were predominantly Soltex, and Steelseal, with lesser quantities of Baracarb and other additives. The additives combined made up between 15 to 25% of the total washed and screened sample examined. At high magnifications it was easy to distinguish dark grayish black lithics of natural origin from dark additives. DEPTH (MD’) DRILL TIME LAG TIME SAMPLE COMPOSITION REMARKS CEMENT FORMATION 3530 10:16 * * * KOP; * sample not required 3540 11:31 11:58 100% - Start collecting spot samples; 3545 12:24 12:50 100% - 108 units gas (polymer); abundant LCM 3550 13:24 13:53 95% ~5% Some siltstone cuttings; abundant LCM 3552 13:48 14: 17 ~80% ~20% More common siltstone; abundant LCM 3554 14:11 14:39 ~70% ~30% Common siltstone; abundant LCM 3556 14:32 15:01 ~50% ~50% Common siltstone, trace quartz sand and dark lithics; sample color medium gray overall indicative of decreasing cement content which gives yellowish- gray color; abundant LCM 3558 14:59 15:28 50% 50% As above with common siltstone, up to 2% fine quartz sand; trace dark lithics; abundant LCM. 3560 15:16 15:57 20% 80% As above with common siltstone; some coarse tuffaceous siltstone, dark lithics, slight increase in fine quartz sand; LCM still common (15-20%) 3562 16:02 16:31 40% 60% 113 units gas – methane and ethane; siltstone with trace coal and sandstone cuttings; common fine quartz sand; LCM still common (15-20%) 3564 16:11 16:39 40% 60% 132 units formation gas; siltstone with trace coal and sandstone cuttings; trace coal; common fine quartz sand; LCM still common (15%) 3566 16:19 16:48 30% 70% Gas increasing; common fine quartz sand, siltstone cuttings; LCM still common (15%). 3568 16:27 16:56 20% 80% Gas increasing; common siltstone, sand, cuttings; ; trace coal; LCM still common (15%). 3570 16:36 17:04 30% 70% Gas increasing; coal gas; coal and siltstone cuttings; some fine quartz sand; LCM 10%. 3575 16:56 17:24 20% 80% Coal gas; coal and siltstone cuttings; some sand; LCM 10%. 3580 17:10 17:38 10% 90% Coal gas; coal and siltstone cuttings; some sand; LCM 10% 3585 17:23 17:52 10% 90% Coal gas; coal and siltstone cuttings; some sand; LCM 10% 3590 17:33 18:02 10% 90% Coal gas; coal and siltstone cuttings; some sand; LCM 10% 3595 17:46 18:05 10% 90% Coal gas; coal and siltstone cuttings; some sand; LCM 3600 18:01 18:21 10% 90% Coal gas; coal and siltstone cuttings; some sand; LCM Mud Weight was maintained in the 9.1 to 9.2 range, with viscosities in the 50-60 range. Anna 17A 6 2.4 Well Resume Operator: Hilcorp Alaska, LLC (Hilcorp Energy Company) Well Name: Anna 17A Field: Granite Point Field – Hemlock Oil Pool County:Kenai Borough State: Alaska – Offshore Cook Inlet – Waters of the United States Company Representatives: Shane Hauck, James Sweetsir, Sloan Sunderland, Richard Brumley Location: Surface Coordinates 794' FNL, 603' FEL, Sec 12, T10N, R12W, SM, AK Ground Elevation 0’ (at MSL) Rotary Table Elevation 121’ AMSL Classification:Sidetrack/Production Well API #: 50-733-20311-01-00 Permit #: 213-049 Rig Name/Type: Inlet Drilling LLC Rig 428 /Arctic Triple Spud Date November 9, 2013 Total Depth Date: 1/2/2014 Total Depth 13,670’ MD/11,297’ TVD Primary Targets Hemlock Oil Pool Primary Target Depths 13600' MD /11603' TVD Total Depth Formation: Hemlock Completion Status: Run 7” Liner to 10620’ 5” Liner to TD LWD-MWD Services. Schlumberger Directional Drilling Schlumberger Wireline Logging Services N/A Drilling Fluids Service Baroid (Halliburton) CANRIG Logging Geologists: James Foradas, Greg Hammond, Josh Dubowski, Dylan Muller CANRIG Sample Catchers: Dean Kekaualua, Dylan Muller, Dickey Hudgins, Ben Calo Anna 17A 7 2.5 Hole Data Hole Section Maximum Depth TD Formation Mud Weight (ppg) Dev. (oinc) Casing Diam. Shoe Depth LOT (ppg) MD (ft) TVD (ft) MD (ft) TVD (ft) Conductor 610’ 609’ Cased hole 9.7* 0.00 20” - - N/A 12 1/4” 3514 3514’ Cased hole 9.7* 0.00 13 3/8” - - N/A KOP 3530’ 3530’ Cement 9.2 18.00 13 3/8” - - N/A 12 1/4” 10,560’ 10,078’ Tyonek 10.1 43.60 9 5/8” 10,471’ 10,022’ 15 ppg 8 1/2” 13,670’ 11,297’ Hemlock 13.6+ 75.21 7” *At time of balancing of Kickoff plug. Note conductor and 13.375” casing to the KOP are part of the previously drilled Anna 17 well. 2.6 Daily Activity Summary November 2, 2013: Mudloggers arrived on platform. DML unit to be spotted in morning. Rig operations include work on high pressure piping, mixing mud, housekeeping, crane, and overboard line projects. November 3, 2013: Rigging up mud logging unit after it was spotted and powered up. Rig operations include work on high pressure piping, mixing mud, standpipe manifold, housekeeping, crane, and overboard line projects including offloading MWD and tools. November 4, 2013: Rig operations include work on mud manifold, steam pipes, vac lines, mixing mud, housekeeping, crane, and overboard line projects. November 5, 2013: Rig operations include welding on MP hard lines; tightening clamps on mud manifold; and C&C pumps at high rate to determine if support for mud manifold and HP piping from pumps is adequate. November 6, 2013: Rig operations: working as directed by operator; crane operations, overboard line projects. Welding padeyes and H/U binders to secure mud manifold; clamp on mud manifold; C&C, pump at 20 bbl/min to determine if support for mud manifold and hp piping from pumps is adequate. pumped through bleeder to hold 400 psi back pressure; ; install/remove wear bushing; remove wear ring; P/U test tools; M/U 5.5" test assembly; P/U test tools ; finish up test joint and put 20K down on test plug; Test BOPs, did nine part test with low of 250 psi and high of 3000 psi with results charted and summary plot produced by Canrig mudloggers; Koomey test; install/remove wear bushing; pull test plug and put wear bushing in; L/D test tool, L/D test joint; house keeping prep for picking up BHA; bolt on mud line brackets; mix mud per mud man; welder making new brackets. November 7, 2013: Rig operations: working as directed by operator; crane operations and house keeping. Welding padeyes and H/U binders to secure mud manifold; mixing mud; welding on HP piping at mud pumps; P/U M/U BHA; C&C; surface test BHA (pumping @ 15 bbls/min @ 900 psi; up wt of tool string 110 K); blow down Top Drive to mud pits; PJSM on slip cut drilling line; slip cut drilling line. November 8, 2013: Service rig. Trip in hole from 765’ to 2960’; break circulation. Drill cement; tag stringers at 3150’; solid at 3198’; average ROP 100 ft/hr to 3349’. Slow pumps due to fluid loss over shakers; work string from 3346’ to 3270’. Drill cement from 3349’ to 3350’. Displace A-17 to new mud; changed mud to 9.2 ppg; clean pits and mud system. Gas as high as 207 units while drilling out cement. November 9, 2013: Clean solids from pits; organize deck; seal under shakers; change out discharge and suction mud pumps; modify damaged screens; transfer fluid to pits. Open BOP; break circulation at 3500’; pump at 16 bbl/min to shear mud and receive survey. Time drill/slide from 3534’ to 3571’. Rotary drill and slide as per DD from 3571’ to 3756’. Anna 17A 8 November 10, 2013: Drill from 3756’ to 4481’ with sweeps at 4046’ and 4232’. Work pipe while circulating bottoms up with one pump. Trip out from 4481’ to 3564’. Work on sand trap and change swab on pump one; rig maintenance. November 11, 2013: Finish rig maintenance; monitor the well. Pressure test both pumps to 2500 psi; test down hole tools and pumps at the shoe. Trip in from 3564’; ream/wash from 4527’. Gas alarm in pits; muster; worked pipe and pumped bottoms up. Drill from 4481’ to 4752’. November 12, 2013: Rotary drilling from 4752’ to 5311’. Slide from 5311’ to 5342’. Rotary drilling from 5342’ to 5420’. November 13, 2013: Drill from 5420’ to 5486’. Pump sweep; work pipe. Attempt to trip out of hole; swabbing; wash out of hole from 5486’ to 3444’; no tight hole. Electrical check and tape up electrical service loop on top drive. Pump dry job; blow down top drive and mud line; trip out of hole to 686’. Turbine generator down; start generators and pumps. Trip out of hole and lay down BHA #1. Service top drive, blocks, crown, drawworks; lay down service loop; calibrate trip tank; rig housekeeping. Move one top drive service loop over and pick up a new service loop. Monitor well on trip tank; static. November 14, 2013: Hang electrical service loop at top drive; rig up electrical lines to top drive and in derrick; test run; secure service loops. Make up BHA #2; fill mud line; check BHA tools. Trip in hole from 655’ to 3454’; circulate bottoms up at shoe. Trip in hole to 5380’; tight spots at 4650’ and 5000’; trip in to 5470’ rotating; circulate bottoms up and work gas out. Drill from 5486’ to 5863’. November 15, 2013: Drill from 5863’-6438’; pump high vis sweep. Trip out of hole from 6438’; tight spot at 6110’; wash tight spot from 6110’ to 6043’; back ream from 6043’ to 6023’; trip out of hole from 6263’ to 5463’. Trip in hole from 5463’ to 6346’; ream and wash from 6346’ to 6438’. Drill from 6438’ to 6636’. Dump sand trap; change shaker screens; clean possum belly; replace shaker rubbers. Drill from 6636’ to 6764’. November 16, 2013: Drill from 6764’ to 7171’. Mud pump 2 shut down; trip out of hole one stand while troubleshooting pump; change shaker screen; tighten hydraulic fitting on top drive; trip back to bottom. Drill from 7171’ to 7428’. Pump sweep for short trip; mud pump 1 down due to liner seal and discharge screen failure; reciprocate from 7311’ to 7408’. Trip out of hole to 6910’; back ream rotating and pumping to 6378’. Trip in hole from 6378’ to 7311’; wash down to 7408’. November 17, 2013: Drill from 7429’ to 7642’; service swivel package on top; check discharge screen #2 mud pump; mix mud; drill from 7642’ to 7790’. Tighten up suction/discharge pod on #1 mud pump; circulate with #2 pump and work pipe. Drill from 7790’ to 8180’. Repair hole in hopper; mix mud; service top drive; grease swivel package and inspect top drive for flow. Drill from 8180’ to 8448’. November 18, 2013: Drill from 8448’ to 8463’. Circulate and condition hole for short trip; short trip from 8463’ to 7548’; several tight spots. Trip in hole from 7548’; ream with one pump to 8180’; trip in hole to 8371’; ream to bottom. Drill from 8463’ to 8945’. Service top drive; grease swivel package, inspect. Drill from 8945’ to 9023’. November 19, 2013: Drill from 9023’ to 9238’. Mud pump 2 tripped offline; 3 times for a total of 30 min; adjust brushes. Drill from 9238’ to 9513’. November 20, 2013: Drill from 9513’ to 9522’. Pump sweep; wash out of hole from 9522’ to 8155’; pump dry job; blow down mud line, standpipe, and top drive for freeze protection; trip out of hole to shoe at 3533’; circulate bottoms up; spot pill; flow check; fill trip tank. Service top drive. Trip out from shoe; shut down twice due to platform electrical issues; close blind rams; clean rig floor. Electrician troubleshooting turbine. Pick up swizzle stick assembly; prepare to rinse stack. November 21, 2013: Run BOP wash tool to wear ring; rig up air line and confirm 4” mud line open to mud pumps; confirm top drive, mud line, and stand pipe open. Filled flow box with mud, ran over beam and out Anna 17A 9 between rig and utility module; clean up; clean mud/cuttings from flow box; clean mud under rig floor. Flush BOP stack; function rams and flush again; lay down wash tool; stand back one stand; drain BOP stack to trip tank. Make up test assembly and pull wear ring; set test plug; make up pump in sub, floor safety valve, dart valve; rig up hoses. Working on low torque valve for kill line on rig floor; suspect frozen—okay; valve working. Lost power to rig. Fill stack with water; thaw out gas buster drain. Test annular, rig floor kill line valve, upper IBOP, choke valves, VBR, kill HCR, dart valve, and floor safety valve. Drawdown; choke HCR; lower P/R. Monitor well. Test blind rams. Lay down test plug; install wear ring. Blow down kill and choke manifold; remove Kelly hose and thaw; thaw frozen top drive; thaw gas buster; thaw lines between RPM and utility modules; reinstall Kelly hose. November 22, 2013: Secure service loop hoses in derrick; blow down choke manifold; lay down 20’ pup and one joint drill pipe; clear floor; bleed 10 psi from well. Pick up BHA; trip in hole to 3440’; circulate four bottoms up. Monitor well for 30 min; test all gas alarms; install deflector guard on tong bucket for service loop; reinstall pull back mule at derrick board. Break out top drive; install safety valve; recharge top drive compensator; install hoist for stabbing board; schrader valve leaked on compensator; replace schrader valve; grease crown and blocks; assist crane crew with drill pipe onto deck. Change out lower IBOP and saver sub; clean mud product from drums for shipping; clean decks and RPM module. Test lower IBOP; blow down choke and top drive; drain poor boy. Pick up torque reducers; change out floor equipment. Pick up 12 joints drill pipe; trip in hole adding torque reducers to 3 singles; stand back; trip in with stands from off driller side installing torque reducers; change tally. November 23, 2013: Trip in; install one NRTR per joint, 14 joints total. Circulate bottoms up @ 3440’; 526u gas. Test 4” mud line to IBOP valve; union leaked; blow down top drive; replace mud line seal rubber; retest to 3500 psi; blow down top drive and mud line. Trip in hole; tag at 4606’; wash to 4656’; gas to 1768u; circulate until down to 150u. Weight indicator not working; wash out of hole to 3490’; hang blocks/top drive; remove drilling line from tie down; change out bad load cell for weight indicator; put drilling line back on deadman; blow down top drive and mud line. Trip back in hole; wash through tight spot at 5020’; gas 668u; trip to 5475’. Trip to 6070’; gas 471u and 716u. Lost power due to intakes packed with snow. Trip in to 7000’; gas 426u. Trip in to 7880’ installing NRTRs. November 24, 2013: Circulate bottoms up at 7880’. Trip in to 9527’ rotating and pumping. Drill from 9527’ to 9574’. Circulate and condition; mud pump 2 overheating with electrical issues. Drill from 9574’ to 9625’. Increase mud weight to 9.9 ppg; troubleshoot mud pump 2. Drill from 9625’ to 9629’. November 25, 2013: Drill from 9629’ to 9716’. Mud pump 2 continues kicking off; work pipe; adjust belts on mud pump 2; pump stopped kicking off. Drill from 9716’ to 9778’. Circulate and condition; up mud weight to 10 ppg; tighten belts on mud pump 2; change out suction; service top drive. Drill from 9778’ to 9833; increase mud weight to 10.2 ppg. November 26, 2013: Drill from 9833’ to 9870’. Work on mud pump 2, still kicking off; work pipe. Drill from 9870 to 10006’. Service top drive; grease wash pipe; monitor electrical synchronization of traction motor for mud pump 2; change shaker screens, flush possum belly and flow line; clean centrifuge. Drill from 10006’ to 10123’; performed kick while drilling drill. November 27, 2013: Drill from 10123’ to 10199’. Trip out of hole to 10010’; electrician changing out boards on pump; trip back to bottom. Drill from 10199 to 10356’. November 28, 2013: Drill from 10356’ to 10560’. Circulate and condition; check for flow. Trip out of hole from 10560’ to 4830’; blow down Kelly and hard lines to mud pumps; fill it. November 29, 2013: Trip out from 4830’ to 3454’ rotating from 4520’ to 4000’, pumping out from 4000’ to 3800’, and pulling dry from 3800’ to 3454’; circulate bottoms up at 3454’. Blow down top drive; monitor well; move Kelly hose to behind service loop; slip and cut drilling line; adjust brakes; grease crown, draw works, and top drive; check oil in top drive, was overfilled, drain two gallons; remove hang line; move top drive to check Kelly hose; adjust brakes again; pressure test Kelly hose and blow down top drive to mud pumps. Trip in from Anna 17A 10 3450’ to 10560’; 675u gas while circulating at 9271’; tagged fill at 10552’; 497u gas while circulating at 10560’. November 30, 2013: Work pipe from 10550’ to 10461’; pump sweep; circulate 14000 strokes. Trip out of hole on elevators from 10550’ to shoe at 3544’; monitor well for flow, static; circulate bottoms up at shoe; pump dry job. Trip out of hole; change out jars; stand back HWDP, flex collars; break off bit; lay down BHA; clear rig floor; lift subs. Change elevators; pick up one joint DP; make up wash tool and crossover; wash BOP stack. December 1, 2013: Clean stack; clean under stripping rubber catch pan and rig floor; remove wear ring for casing run. Pick up test tools; make up 9-5/8” test joint; change bottom rams to 9-5/8”; 9-5/8” BOP test failed; changed test joint to seal on a different spot; could not test; rebuild 9-5/8” rams; change out rubber; fix hydraulic leak on door; reinstall 9-5/8” rams; recharge Koomey unit and fill stack with water; test 9-5/8” rams to 3000 psi. Blow down top drive, mud line; rig down test hoses; lay down testing assembly. Clean up pits and mud from trip out. Lay down 5-1/2” elevators and bails. Move CRT to rig floor; make up to top drive; rig up wotco to run 9-5/8” casing; CRT, tongs, spider, and safety valve. Pick up 9-5/8” shoe joint; move centralizer and top rings to 10’ above shoe; trip in hole. December 2, 2013: PJSM for sunning 9-5/8” casing and CRT operation. Make up the first three joints with baker lock and pump; returns to shakers; check float equipment. Run casing to 3502’; pump bottoms up, 186u gas; circulate while offloading 99 joints casing from boat; run casing in to 5075’; pump bottoms up, 317u gas; run casing to 5373’; 132 joints in hole. December 3, 2013: Run casing from 5373’ to 7510’; fill on every sixth joint running in; work pipe and pump, max gas 537u; run casing to 10422’; make up hanger and landing joint; circulate two bottoms up, max gas 485u; work down to 10480’ while circulating; attempted to reciprocate and could not pick up; land 9-5/8” casing at 10483’; set in hanger. Release CRT from landing joint; blow down CRT and top drive. Rig up cementing head, lines, and valves; circulate through cementing head. PJSM for cement job. SLB pump 5 bbl water; test lines to 5000 psi; rig pump 40 bbl 10.5 ppg mud push; chase with 8 bbl mud; SLB drop bottom plug while started pumping cement; SLB pump 450 bbl 12.5 ppg lead cement; follow with 43.5 bbl 15.8 ppg tail cement; SLB drop top plug and chase with 5 bbl water. Rig displace with 10.1 ppg mud; 650 bbl away. December 4, 2013: Displace cement with 10.1ppg mud. took 766 bbls to bump plug to 1300 psi. Bleed down casing and had 3.5 bbls return. Test casing on chart for 30 min to 1500 psi. Blow down all lines and R/D casing/cementing equipment. clean and clear rig floor. Pick bails up and put elevators on. P/U BHA with 4 stands of HWDP and RTTS. RTTS would not make up. Break connection and clear tool. M/U 9 5/8" RTTS to 5 1/2" DP. TIH and set RTTS @ 96'. TIH LD RNG tool stand back DP. Pressure test down to RTTS @1500 psi for 15 min. ok. Bleed off pressure and BD mud lines. P/U 1 stand 5 1/2" DP. TIH and L/D top single. R/U head pin and valve hose. Flush BOP stack and drain down below 9 5/8" hanger. R/D head pin, valve, hose and stand back in derrick. December 5, 2013: Continue nippling up BOP's while performing miscellaneous rig maintenance and installing iron roughneck. December 6, 2013: Finish installing iron roughneck, continue rig maintenance and prep for BOP's test. December 7, 2013: P/U test joint and R/u to test BOP's. L/D test joint and R/D BOP testing equipment. Take on DP and continue rig service. December 8, 2013: Continue with rig service. P/U BHA #4 and TIH. Shallow test MWD tools and continue TIH. December 9, 2013: Continue RIH to 7099' and CBU 3x Slip and cut drill line and service top drive; rack back 6 stands; continue RIH, installing NRP's. December 10, 2013: RIH to 10,200', installing NRP's. TOOH to 6,720'. Pick up 78 joints of 5.5" DP and rack Anna 17A 11 back 26 stands. Pick up 42 joints 5.5" DP. December 11, 2013: Continue tripping into hole and tag cement. CBU and test casing to 4000 psi. Drill out cement and 20' of new hole. FIT to 15ppg and begin drilling. Drilling ahead at 10739' at report time. December 12, 2013: Drilled ahead to 11076'. Top drive fails and pump out two stands before having to shut down top drive and troubleshoot while slow pumping. Inside casing while circulating and weighing up mud. December 13, 2013: Continue circulating while repairing top drive. December 14, 2013: Continue circulating above the shoe while repairing top drive. Wash/ream down to TD and begin drilling. December 15, 2013: Drilled ahead to 11463' when swivel packing began to leak. Shut down and replaced swivel packing while slow pumping. Continued drilling ahead to 11629' at report time. December 16, 2013: Drilled ahead to 12,041', CBU and perform a short trip to 11075'. Wash and ream back to bottom and begin drilling ahead to 12097’ at report time. December 17, 2013: Drilled ahead to 12211' and lost power from production. Fixed power issue and continued drilling ahead to 12316' at report time. December 18, 2013: Drilled ahead to 12493' at report time. December 19, 2013: Drilled ahead to 12532'. Circulate bottoms up and begin POOH. December 20, 2013: Continue POOH through tight spots. December 21, 2013: Continue POOH through tight spots. December 22, 2013: Continue POOH through tight spots. December 23, 2013: Continue POOH through tight spots. December 24, 2013: Continue POOH to the shoe. CBU with very little cuttings returned. Pumped a dry job and tripped the rest of the way out of the hole with no problems. December 25, 2013: L/D BHA and R/U BOP test equipment and test BOP's. Service Top drive then P/U new BHA and RIH while attaching NRTR's at report time. December 26, 2013: Continue TIH, replacing NRTR's. Circulate while slipping and cutting drill line. Pump dry job and begin POOH at report time. December 27, 2013: Finish POOH and L/D BHA. P/U drilling BHA while servicing rig pumps. RIH to 10738' then pull back into shoe to service top drive. Resume RIH at report time. December 28, 2013: Continue Washing and reaming to bottom through tight spots. Tag bottom and pump high vis sweep. Drill ahead to 12685' at report time. December 29, 2013: Drill ahead to 12910. Over pulled while back reaming before connection. Attempted to loosen pipe through alternating pumps rates, jarring and working pipe. Freed pipe and POOH 8 stands. Running back in at report time. Anna 17A 12 December 30, 2013: Drill ahead to 13104 and short trip out 5 stands. Running back into hole at report time. December 31, 2013: Wash back to bottom and drill. Drilling ahead at 13274' at report time. January 01, 2013: Continue drilling ahead to 13531 at report time. January 02, 2013: Drilled ahead to TD at 13670'. CBU and begin POOH through tight spot at 13180'. Begin pumping out to 12578' encountered another tight spot. Setting off jars and working hole at report time. January 03, 2013: Continue MAD passing/POOH through tight spots. January 04, 2013: Continue POOH through tight spots. January 05, 2013: Continue POOH through tight spots. January 06, 2013: Finished POOH and discovered clamp on stabilizer was left in hole. Running in hole to replace WWT torque reducers at report time. January 07, 2013: Finished replacing worn NRP's and racked back DP. R/U wirline and ran caliper log. Rigging up to test BOP's at report time. January 08, 2013: Finished testing BOP's and Rig down testing equipment. R/U Weatherford casing equipment and prep to RIH with 7" liner. January 09, 2013: Running in hole with 7" liner at 10,170' at report time. January 10, 2013: Continue RIH with 7" liner. CBU before getting into open hole at 10620'. Work through tight hole at 10280', 11636', 12584' and 12896'. Liner was detained at 12897, lost circulation and pipe rotation. Attempted to pull up to 660K with no luck. Decision was made to set hanger and TOOH. While pressuring up to set hanger @ 1950 the psi broke over and mud was injected away at 4-5 bbls/min. Released from hanger and established circulation. no losses following release. POOH at report time. January 11, 2013: Finished POOH and L/D 5.5" DP and HWDP. Changed out upper rams and testing BOP's at report time. January 12, 2013: Finish testing BOP's and begin P/U 4" DP. Shut down due to turbine failure. Troubleshooting at report time. January 13, 2013: Continue waiting on parts for turbine while servicing the rig. January 14, 2013: Waiting on parts for turbine while servicing the rig January 15, 2013: Service rig, change out circuit breaker on generator #2, circulate and condition mud, trip in hole from 3878' to 10239', circulate and condition mud, trip in hole to 12,738', set cement retainer at 12735', circulate, start pulling out of hole to 7,505' at report time. January 16, 2013: Pull out of hole from 7,505', log cased hole, perforate casing, pick up BHA, make up baker cement retainer, trip in hole with cement retainer to 10051' at report time. January 17, 2013: Trip in hole with cement retainer from 10051’ to set retainer at 12398’, circulate and condition mud, rig up cement line, pressure test cement lines, pump cement and spacer, start pulling out of hole to 11871' at report time. January 18, 2013: Pull out of hole and lay down Baker tools, service and clean rig, pick up BHA/change Anna 17A 13 out elevators, trip in hole to 9368’, wash to tag cement @ 9411’, circulate and condition mud, pull out of hole to 539’ at report time. January 19, 2013: Pull out of hole and lay down Baker tools, change elevators, pick up packer and trip in hole to 6321’, cut and slip drill line, service rig, trip in hole to 9391’, circulate and condition mud, pressure test cement lines, seat ball in packer, release from packer and pull out of hole to 6037’ at report time. January 20, 2013: Pull out of hole from 6037’, lay down BHA and packer, run wireline logs, rig up and test casing, test BOP’s. January 21, 2013: Test BOP’s, pick up BHA, trip in hole to 9360’, wash down and tag cement at 9409’, circulate and condition mud, pump slug, pull out of hole to 3205’ at report time. January 22, 2013: Pull out of hole, lay down BHA, pick up mill bit, trip in hole to 9368’, wash to tag cement at 9408’, mill and dress liner to 9411’, pull out of hole and lay down BHA. January 23, 2013: Pick up BHA, trip in hole with mill assembly, tag packer at 9403’, mill and dress packer from 9403’ to 9405’, wash down to 9430’ at report time. January 24, 2013: Circulate and condition mud, pull out of hole and lay down BHA, pick up 6” bit and clean out assembly with BHA, trip in hole to 12354’, drill cement to 12442’ at report time. January 25, 2013: Drilling cement from 12442’ to 12456’, washing and reaming from 12456’ to 12779’, drilling cement from 12779’ to 12914’, working stuck pipe at 12914’, jar pipe loose, circulate and condition mud and re-drill shoe from 12910’ to 12911’ at report time. January 26, 2013: Drilling cement from 12911’ to 12914’,back ream to 12845’, wash and ream from 12845’ to 12921’, back ream to 12900’, ream to 12935’, packed off , back ream circulate and condition mud, pull out of hole, lay down bit and stabilizers at report time. January 27, 2013: Pick up BHA, trip in hole with 6” bit to 10225’, cut and slip drill line, trip in hole from 10225’ to 12900’, wash and ream from 12900’ to 12931’. Max gas last 24 hours 8 units. January 28, 2013: Washing and reaming from 12931’ to 12942’, packed off, work back into shoe at 12908’, circulate and condition mud, washing and reaming from 12908’ to 12980’, packing off at 12980’, working tight spot 12980’ to 12905’, pulling out of hole from 12905’ to 11616’ at report time. Max gas last 24 hours 23 units reaming @ 12970’. January 29, 2013: Pull out of hole and lay down BHA, pick up new BHA, trip in hole to 12866’ scraper @ 12852’, circulate and condition mud, pull out of hole from 12866’ to 9280’ at report time. Max gas last 24 hours 2 units. January 30, 2013: Pull out of hole and lay down BHA, Pick up plug tools, trip in hole to 12850’, circulate and condition mud, pressure up to 2000 psi for 2 min., pick up to 1242’ and pressure up to 3000 psi, attempt to reverse circulate to 2000 psi, test casing @ 1000 psi bled to 830 psi and held. Anna 17A 14 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Prognosed and observed tops were provided by Hilcorp geologist Jacob Dunston based on the results of wireline logging operations. NAME LITHOLOGY PROGNOSED OBSERVED MD TVDSS TVD MD TVDSS TVD Kickoff Point Beluga Fmn 3314’ Selected Beluga Markers: BM-5 Coal 3,560 -3,378 3,502 ** ** ** BM-4 Coal 3,742 -3,552 3,676 3,738 -3,548 3,672 BM-3 Coal 3,795 -3,602 3,726 3,795 -3,603 3,727 BM-2 Coal 3,923 -3,724 3,848 3,920 -3,722 3,846 BM-1 Coal 4,034 -3,831 3,955 4,023 -3,821 3,945 Top of Tyonek Selected Tyonek Markers: TM-X Coal 4,088 -3,883 4,007 ** ** ** TM0 Coal 4,156 -3,948 4,072 4,143 -3,935 4,059 TM1 Coal 4,354 -4,138 4,262 4,325 -4,109 4,233 TM1A Coal 4,445 -4,225 4,349 4,409 -4,190 4,314 TM2 Coal 4,580 -4,355 4,479 4,549 -4,322 4,446 TM3 Coal 4,674 -4,445 4,569 4,637 -4,407 4,531 TM4 Coal 4,748 -4,515 4,639 4,714 -4,479 4,603 TM6 Coal 4,918 -4,678 4,802 4,872 -4,630 4,754 TM7 Coal 5,083 -4,835 4,959 5,020 -4,770 4,894 TM8 Coal 5,186 -4,935 5,059 5,130 -4,875 4,999 TM9 Coal 5,310 -5,053 5,177 5,251 -4,990 5,114 TM10 Coal 5,443 -5,180 5,304 5,388 -5,121 5,245 TM11 Coal 5,509 -5,243 5,367 5,446 -5,176 5,300 TM13 Coal 5,630 -5,359 5,483 5,574 -5,299 5,423 TM14 Coal 5,745 -5,468 5,592 5,575 -5,300 5,424 TM15 Coal 5,827 -5,547 5,671 5,689 -5,411 5,535 TM16 Coal 5,909 -5,625 5,749 5,771 -5,490 5,614 TM17 Coal 6,086 -5,795 5,919 5,843 -5,560 5,684 TM18 Coal 6,331 -6,029 6,153 6,023 -5,734 5,858 TM19 Coal 6,537 -6,226 6,350 6,283 -5,988 6,112 TM20 Coal 6,735 -6,416 6,540 6,474 -6,174 6,298 TM21 Coal 6,837 -6,513 6,637 6,670 -6,364 6,488 TM22 Coal 6,933 -6,605 6,729 6,779 -6,471 6,595 TM23 Coal 7,092 -6,757 6,881 6,875 -6,563 6,687 TM24 Coal 7,171 -6,833 6,957 7,038 -6,722 6,846 Anna 17A 15 NAME LITHOLOGY PROGNOSED OBSERVED MD TVDSS TVD MD TVDSS TVD TM25 Coal 7,232 -6,891 7,015 7,119 -6,801 6,925 TM26 Coal 7,317 -6,973 7,097 7,189 -6,869 6,993 TM27 Coal 7,390 -7,042 7,166 7,278 -6,955 7,079 TM28 Coal 7,468 -7,116 7,240 7,347 -7,023 7,147 TM29 Coal 7,540 -7,186 7,310 7,430 -7,104 7,228 TM30 Coal 7,623 -7,264 7,388 7,501 -7,173 7,297 TM31 Coal 7,688 -7,327 7,451 7,596 -7,265 7,389 TM32 Coal 7,762 -7,398 7,522 7,663 -7,330 7,454 TM33 Coal 7,827 -7,460 7,584 7,732 -7,397 7,521 TM33A Coal 7,879 -7,510 7,634 7,810 -7,474 7,598 TM34 Coal 8,061 -7,684 7,808 8,062 -7,720 7,844 TM35 Coal 8,128 -7,748 7,872 8,132 -7,788 7,912 TM35A Coal 8,198 -7,814 7,938 8,197 -7,851 7,975 TM36 Coal 8,268 -7,882 8,006 8,288 -7,940 8,064 TM37 Coal 8,304 -7,916 8,040 8,325 -7,976 8,100 TM38 Coal 8,367 -7,976 8,100 8,378 -8,028 8,152 TM38A Coal 8,400 -8,008 8,132 8,413 -8,062 8,186 TM39 Coal 8,552 -8,153 8,277 ** ** ** TM39A Coal 8,567 -8,168 8,292 8,549 -8,194 8,318 GP-C1 Sand 8,568 -8,169 8,293 ** ** ** Top Of Swept/Wet Tyonek Sands Interval: C-2A Marker Coal 8,739 -8,332 8,456 8,817 -8,453 8,577 C-2 Sand 8,806 -8,396 8,520 8,881 -8,515 8,639 C-3 Marker Coal 8,860 -8,448 8,572 8,933 -8,565 8,689 C-4 Marker Coal 8,892 -8,478 8,602 8,975 -8,605 8,729 COAL Coal 8,944 -8,528 8,652 ** ** ** C-5 Marker Coal 8,984 -8,566 8,690 ** ** ** C-5A * Sand 9,028 -8,609 8,733 9,043 -8,670 8,794 C-5B Marker Coal 9,107 -8,684 8,808 ** ** ** C-5B Sand 9,119 -8,696 8,820 9,176 -8,795 8,919 TM42A Coal 9,178 -8,752 8,876 ** ** ** C-6 Marker * Coal 9,210 -8,783 8,907 ** ** ** C-6 Sand 9,236 -8,808 8,932 9,299 -8,908 9,032 C-6B Sand 9,257 -8,827 8,951 9,333 -8,939 9,063 TM44 Coal 9,347 -8,914 9,038 9,424 -9,022 9,146 C-7A Marker Coal 9,390 -8,955 9,079 9,496 -9,087 9,211 C7AT Sand 9,436 -8,999 9,123 9,539 -9,126 9,250 C-7B Marker Coal 9,455 -9,017 9,141 ** ** ** C7B_UPPER Sand 9,464 -9,026 9,150 9,589 -9,171 9,295 Anna 17A 16 NAME LITHOLOGY PROGNOSED OBSERVED MD TVDSS TVD MD TVDSS TVD Top Of Produced Tyonek Oil Sands Interval: C-7C Marker Coal 9,514 -9,073 9,197 9,623 -9,200 9,324 C7CT Coal 9,523 -9,082 9,206 ** ** ** C7DT Coal 9,614 -9,169 9,293 9,715 -9,282 9,406 C7ET Coal 9,663 -9,216 9,340 9,746 -9,309 9,433 C-8 Marker Coal 9,688 -9,240 9,364 9,864 -9,410 9,534 C-8A Sand 9,706 -9,257 9,381 9,868 -9,413 9,537 C-8B Marker Coal 9,741 -9,290 9,414 ** ** ** C-8B Sand 9,751 -9,300 9,424 9,908 -9,447 9,571 C-8C Sand 9,813 -9,358 9,482 9,986 -9,512 9,636 C-8D Marker Coal 9,875 -9,416 9,540 ** ** ** C-8D Sand 9,890 -9,430 9,554 10,068 -9,578 9,702 TM46A Coal 9,970 -9,504 9,628 10,179 -9,667 9,791 TM46B Coal 10,010 -9,540 9,664 10,218 -9,697 9,821 C-9A Sand 10,025 -9,555 9,679 10,246 -9,719 9,843 TM47 Coal 10,115 -9,635 9,759 10,326 -9,780 9,904 C-9B Marker Coal 10,175 -9,688 9,812 ** ** ** C-9B Sand 10,205 -9,714 9,838 10,402 -9,838 9,962 C-9C Marker Coal 10,275 -9,775 9,899 10,472 -9,890 10,014 C-9C Sand 10,300 -9,796 9,920 10,652 -10,017 10,141 C-10 Coal 10,540 -9,992 10,116 10,889 -10,175 10,299 TM54A Coal 10,946 -10,282 10,406 ** ** ** TM55A Coal 11,106 -10,380 10,504 11,499 -10,497 10,621 Production Target Interval Hemlock formation (Oil): Top of Hemlock Coal 11,510 -10,579 11,624 ** ** ** Hemlock 1A Sand 11,540 -10,590 10,714 11,948 -10,664 10,788 Hemlock 1B Sand 11,657 -10,633 10,757 12,032 -10,693 10,817 Hemlock 2 Sand 11,780 -10,673 10,797 12,087 -10,713 10,837 Coal Coal 12,083 -10,771 10,895 ** ** ** WF Marker Sand/Shale 12,470 -10,897 11,021 12,478 -10,844 10,968 WF-Repeat Sand/Shale * * * 13,205 -11,054 11,178 COAL Coal * * * ** ** ** Hemlock 2-Repeat Sand * * * 13,569 -11,146 11,270 Hemlock 2 1B- Repeat Sand * * * ** ** ** Hemlock 2 1A- Repeat Sand * * * 13,660 -11,169 11,293 Total Depth 13,600 11,603 ** ** ** Note: All data on this table was provided by the Wellsite Geologist and included in the permit application. *Prognoses were not available at spud. **Final Tops not provided. Anna 17A 17 3.2 Lithologic Details Full service mudlogging initiated after kickoff at 3314’ MD/780’ TVD. Above this interval is cased hole in the Sterling and Upper Beluga formations as identified in well logs for the Anna 17 well. Sample descriptions provided by Canrig after drilling out of cemented casing follow: Siltstone (3550' - 3620') = dark gray to dark greenish gray; soft friable to crumbly; earthy to rare planar fracture; massive to wedgelike cuttings; silty to clayey predominant with occasional sucrosic and sandy texture; massive structure; interbedded with fine to very fine sands and tuffaceous sandstone; coals in upper interval are non vitreous flaky sub bituminous; cement fraction decreases to rare; scattered mud additive contamination. Sand/Sandstone (3620' - 3675') = olive gray to dark gray; upper medium to upper fine grading to very fine; quartzose with gray to black lithics; trace jasper and rare dark greenish gray lithics; well sorted; subangular to sub round; spheroidal to subdiscoidal; loose sand and fragments of soft Tuffaceous sandstone predominant with occasional brittle fragments with calcareous cement. Siltstone (3675' - 3740') = dark gray to olive black; soft friable to mushy; silty to clayey; non cohesive; non to weakly adhesive; massive with occasional irregular bedding and fracture; scattered carbonaceous siltstone/claystone with lignitic microlamina; scattered sand, brittle very fine sandstone fragments, and soft Tuffaceous sandstone. Coals (3740' - 3800') = sub bituminous; blocky to conchoidal to flaky to hackly fracture; resinous to earthy luster; occasional carbonaceous siltstone microlamina; moderate offgassing at 10 min decreasing to rare weak offgassing at 2 hrs. Siltstone/Claystone (3800' - 3890') = olive gray to dark gray with secondary brownish black; soft friable to mushy crumbly clayey siltstone to soft smooth claystone; grades to very fine sandy siltstone; non to weakly cohesive and adhesive; massive to wedgelike cuttings; irregular to earthy planar fracture; massive with rare carbonaceous microlamina; scattered weakly calcareous; becomes increasingly clayey in lower interval with carbonaceous microlamina becoming common and scattered fragments of silt/coal and sandstone/coal micro laminations; rare brittle grain supported fine to very fine grained sandstone fragments with calcite cement. Claystone/Siltstone (3890' - 3990') = olive gray to dark gray with pale brown to brownish black hues; cohesive and somewhat adhesive; clumpy to mushy; crumbly to pulverulent; irregular blocky fracture; nodular to wedgelike cuttings habit; waxy to dull earthy luster; smooth to mottled texture; massive to laminar structure with some dark carbonaceous laminae; intergrading to siltstone; Tuffaceous in part; slight to moderately calcareous; interbedded with thin Tuffaceous sandstone, coal, and carbonaceous shale beds. Coal (3930' - 3980') = black to brownish black; lignitic to medium bituminous grade; crunchy to tough; wedgelike to tabular; dull to vitreous; matte texture; cuttings commonly offgassing; occurs as thin beds interbedded with claystone, siltstone and thinner sand and shale beds; correlates with the predicted depth of the bm-2 coal. Claystone/Siltstone (3990' - 4080') = olive gray to dark gray with pale brown and yellowish hues; clumpy to pasty; slightly adhesive; pulverulent and crumbly varieties where silty; irregular blocky fracture; tabular, wedgelike and nodular cuttings habits; dull earthy luster; smooth to gritty textures; thin to laminar structure; predominantly Tuffaceous; intergrading to very fine Tuffaceous sandstone in places; Tuffaceous Sandstone (4080' - 4200') = medium to dark gray with light gray and pale brown hues; lower Anna 17A 18 very fine to upper fine grained; poor to well sorted; angular to subrounded grains; very low to moderate sphericity; some impact and grinding surface features on grains; mod hard to easily friable; mostly grain supported with common silty Tuffaceous matrix; composed of quartz and volcanic lithics; non- to very calcareous; yellow sample fluorescence from mud additive; sample includes predicted TM-X marker. intergrades to finer Tuffaceous rocks. Coal (4140 - 4180') = black; tough to brittle; splintery to blocky fracture; tabular wedgelike cuttings; resinous to vitreous luster; low to medium grade bituminous; smooth texture; common thin laminae, some possibly pyritized; vigorous off gassing common on many coal cuttings; interbedded with Tuffaceous siltstone; coal cuttings depths consistent with predicted TM-0 marker and TM1 coal depths for well. Tuffaceous Sandstone (4210' - 4290') = medium to light gray with olive and yellowish brown hues; lower very fine to lower medium with some coarse grains; fair to well sorted; subangular to round; low to moderate sphericity; impact and frosting surface features; unconsolidated to easily friable; some silica cement; grain supported with some silty Tuffaceous matrix; composed of volcanics and quartz with common dark volcanic and carbonaceous fines; both compositionally and texturally sub mature; slight pale yellow fluorescence of samples may be due to mud additives, intergrading with Tuffaceous siltstone and interbedded with thin sand stringers and occasional thin coal stringers. The rocks sampled in this interval resemble those predicted below the TM-1 marker. Coal (4320' - 4360') = black; tough to brittle; splintery to planar fracture; tabular to elongated wedgelike cuttings habit; resinous to vitreous luster; smooth to matte texture; common thin laminae; thin beds; cuttings vigorously offgassing; these coals appear to be the coal at the TM-1 marker and above it. Tuffaceous Claystone (4360' - 4390') = light to medium gray with pale yellow hues; somewhat adhesive; curdy to pasty; irregular fracture; tabular to nodular cuttings; dull earthy luster; gritty to granular texture intergrading to matrix supported fine sandstone; interbedded with stringers of coarse quartz sand, some with traces of greenstone. Tuffaceous Sandstone/Conglomeratic Sand (4390' - 4430') = dark gray to olive gray; salt and pepper appearance; quartz predominant with gray to black lithics and clastic coal; rare greenish gray, moderate brown, and jasper; lower fine to lower medium grading to 3mm granule; well sorted; subangular to well rounded; moderate to high sphericity; loose grains predominant with common soft tuff/silt matrix; scattered moderately calcareous; grades to and interbedded with sandy siltstone/claystone. Tuffaceous Sandstone/Sand (4480' - 4550') = dark greenish gray to light olive gray; quartzose with gray lithics common; trace jasper and chlorite; very fine to fine in soft tuff matrix support with medium to coarse in loose grains; well sorted overall; subangular to sub round with angular volcanic fines; non to weakly calcareous; rare silica cement Tuffaceous Siltstone (4550' - 4590') = dark gray; olive gray hue; secondary brownish black; soft with scattered tough brittle shaly fragments; massive cuttings; massive structure with occasional carbonaceous microlamina; silty to sandy; crumbly to flexible; moderately to non adhesive. Tuffaceous Sandstone (4590' - 4640') = medium gray to olive gray; lower medium to lower fine grading to very fine sandy siltstone; quartzose with dark gray lithics; scattered tuff clasts; rare jasper and chlorite; well sorted; subangular to angular; to rounded in rare coarser grains to 3mm; soft tuff/silt matrix support; common grain support in lower fine grained fragments. Coal (4640' - 4650') = sub bituminous to silty lignite; blocky to earthy fracture; resinous to earthy luster; even moderate offgassing immediately decreasing to scattered weak at 2 hrs; correlates with TM-3. Tuffaceous Siltstone (4650' - 4720') = dark gray to dark greenish gray; soft mushy to crumbly; massive; sandy to clayey; silty claystone adhesive. Anna 17A 19 Coal (4720' - 4730') = sub bituminous; resinous to dull; blocky; weak immediate offgassing; correlates with TM-4. Tuffaceous Siltstone/Claystone (4730' - 4820') = dark gray to dark greenish gray with scattered grayish brown tuff fragments; soft predominant with occasional dense to brittle shay siltstones; silty with very fine sands to silty claystone; silty portions crumbly and non adhesive grading to adhesive clays; scattered minor carbonaceous microlamina; massive structure predominant; rare brittle grain supported Tuffaceous sandstone fragments; trace tuff fragments; scattered moderately to weakly calcareous. Tuffaceous Siltstone (4820' - 4875') = dark gray to olive gray; soft mushy to crumbly; clayey predominant with some cleaner silts; massive structure predominant with rare subtle tuff micro bedding; scattered moderately hard crunchy lower medium to lower fine grain supported Tuffaceous sandstone with calcite cement; non to scattered weakly calcareous overall. Coal (4875' - 4890') = sub bituminous; blocky to irregular to conchoidal fracture; resinous to dull; even moderate immediate offgassing; correlates to TM-6 Tuffaceous Siltstone (4870' - 4930') = light to medium gray with brownish hue; crumbly to pulverulent; irregular blocky fracture; tabular to nodular cuttings; dull earthy luster; gritty to colloidal textures; thin structure; common dark fines; intergrading to sandstone; occurs in thin beds with thin Tuffaceous shale, carbonaceous shale and coal stringers. Tuffaceous Sandstone (4930' - 5060') = light to medium gray with pale brown and darker gray brown hues; lower very fine to lower medium grain, coarsening down; poor to fair sorted; subangular to subrounded; moderate sphericity; easily friable to friable; trace to very calcareous; some calcite cement; grain supported with common Tuffaceous silt matrix; composition mostly volcanic rock fragments with some quartz; trace greenstone; intergrades to Tuffaceous siltstone in places. Coal (5020' - 5045') = black with dark reddish brown hues; dense; conchoidal to splintery fracture; resinous to dull; matte texture; thin laminated structure; many pyritized; thick beds in Tuffaceous sandstone; correlates to TM-7. Tuffaceous Sandstone (5060' - 5160') = light to medium gray with pale brown and yellow gray hues; upper very fine to lower coarse grain; some coarsening down; fair to well sorted; subangular to subrounded; sphericity is moderate to low; firm to friable; calcareous in part; some calcite and silica cement; grain supported with common Tuffaceous silt matrix; composition mostly volcanic rock fragments with some quartz; trace greenstone and fragments of yellow tuff; intergrades to Tuffaceous siltstone and interbeds with thin coal stringers. Coal (5140' - 5150') = black with medium brown hues; brittle; planar to splintery fracture; resinous to dull; tabular cuttings habit; matte texture; thin beds of lignitic to medium grade bituminous; correlates with TM- 8. Tuffaceous Sandstone (5150' - 5250') = light to medium brownish gray with pale brown gray hues; upper very fine to lower coarse grain with some coarser poor to fair sorted; angular to well rounded; sphericity is moderate to low; firm friable to unconsolidated; non- to moderately calcareous; some cement; grain supported with ample Tuffaceous silt matrix in some specimens; composed of volcanics with some coarse quartz; trace greenstone and yellow tuff; intergrades to Tuffaceous siltstone and claystone in places; interbedded with thin coal and coarse sand stringers. Coal (5250' - 5260') = gray black; tough to dense; blocky to splintery; tabular wedgelike cuttings habit; resinous to vitreous luster; matte to mottled texture; common laminae; occurring in thin to thick beds; correlates with TM9. Anna 17A 20 Tuffaceous Sandstone/Sand (5260' - 5370') = olive gray to dark gray; upper fine to upper medium predominant; common coarse to rare granule fragments; common volcanics to very fine and silt sized; well sorted; spheroidal to subdiscoidal; subangular to angular predominant; sub round common; quartzose with gray to black lithics; rare translucent to opaque grayish green lithics; trace moderate brown volcanics; soft tuff matrix support predominant; abundant loose grains; scattered brittle grain support; moderately to noncalcareous; interbedded with sandy siltstones and scattered micro laminated carbonaceous siltstone; rare yellowish gray tuff fragments; dull fluorescence from mud and spot mineral fluorescence. Coal (5390' - 5405') = sub bituminous; blocky to concohidal to splintery fracture; scattered moderate immediate offgassing; resinous to dull with rare vitreous micro banding; correlates to TM-10. Tuffaceous Siltstone (5370' - 5485') = olive gray to medium gray; sandy to clayey siltstone with silty claystone; soft; massive; scattered carbonaceous microlamina; interbedded with soft Tuffaceous sandstones; scattered sand. Coal (5445' - 5455') = sub bituminous; scattered weak offgassing; resinous to earthy; partly silty; correlates to TM-11 Tuffaceous Siltstone (5485' - 5600') = olive gray to very dark gray; sandy siltstone grading to siltstone and silty claystone; soft crumbly to mushy predominant with trace brittle shaly cuttings; common carbonaceous silts and microlamina; massive to occasionally micro bedded structure; massive to wedgelike cuttings with common PDC bit cut; common upper fine to lower coarse subangular to angular sands; scattered weakly calcareous; two minor coals correlating to TM-12 markers. Coal (5570' - 5580') = sub bituminous; blocky to irregular to trace conchoidal; dull to resinous; correlates to TM-13. Tuffaceous Sandstone (5600' - 5690') = olive gray to medium gray; secondary yellowish gray tuff; upper fine to upper medium predominant with abundant very fine volcanics and scattered to coarse; well sorted; subangular to angular with subrounded coarse; quartzose with gray to black lithics predominant; trace opaque moderate brown volcanics and translucent greenish gray lithics; scattered to abundant soft tuff fragments; soft tuff/silt matrix support predominant with rare brittle grain support; massive structure predominant with rare to common carbonaceous microlamina and subtle tuff bedding; strongly calcareous in part; interbedded with sandy siltstones as above. Coal (5690' - 5720') = sub bituminous; irregular to blocky to splintery fracture; dull to resinous; grades to and interbedded with carbonaceous siltstone; occasional weak immediate offgassing; correlates to TM-14 coals. Tuffaceous Sandstone (5720' - 5775') = olive gray; lower very fine to upper fine soft Tuffaceous sandstone grading to sandy Tuffaceous siltstone; loose sand to lower medium and scattered lower coarse; well sorted; subangular to angular; trace yellowish gray tuff fragments; lithic sub quartzose; non to commonly very calcareous. Coal (5775' - 5780') = sub bituminous; irregular to blocky fracture; predominantly silty; correlates to TM- 15. Tuffaceous Sandstone (5780' - 5845') = olive gray; moderate salt and pepper appearance; lower fine to lower medium grading to very fine volcanics; scattered to very coarse; well sorted; subangular to angular with sub round coarser grains; soft tuff/silt matrix predominant with abundant to common loose grains; common tuff fragments; non to moderate calcareous. Coal (5845' - 5855') = sub bituminous; blocky to conchoidal to splintery with silty portions irregular; correlates to TM-16. Anna 17A 21 Tuffaceous Sandstone/Sand (5870 - 5990') = olive gray to medium gray; quartzose with gray to black lithics; rare jasper, greenish gray, and moderate brown volcanic lithics; common to scattered yellowish gray tuff fragments; lower fine to upper medium predominant grading to very fine volcanics with occasional coarse to granule grains and 4mm fragments; soft tuff/silt matrix predominant; mushy to crumbly; occasionally crunchy to brittle; subangular to angular; moderately calcareous in part; grades to and interbedded with sandy Tuffaceous siltstone; occasional carbonaceous siltstone fragments; occasional brittle to dense very dark gray sub fissile shaly fragments. Tuffaceous Siltstone (5990' - 6030') = dark olive gray to very dark gray; dense brittle to crumbly to soft; massive to wedgelike to blocky cuttings; silty to clayey texture; rare carbonaceous microlamina; noncalcareous; non cohesive and non adhesive predominant. Coal (6030' - 6060') = sub bituminous; blocky to irregular to splintery to conchoidal fracture; dull to resinous luster with trace vitreous micro banding; scattered to trace weak immediate offgassing; correlates to TM-17. Tuffaceous Siltstone/Carbonaceous Siltstone/Shaly Siltstone (6060' - 6140') = olive gray to medium gray with dark olive gray and very dark gray; interbedded soft mushy sandy Tuffaceous siltstone, soft crumbly carbonaceous siltstone, dense carbonaceous shaly siltstone, dense brittle shaly siltstone, and soft Tuffaceous silty sandstone; scattered brittle Tuffaceous sandstone fragments and loose sand; massive structure predominant with common carbonaceous microlamina and rare tuff bedding; noncalcareous. Tuffaceous Siltstone (6140' - 6200') = olive gray to light olive gray; crunchy to crumbly to brittle tenacity; earthy fracture; sub tabular to sub wedgelike cuttings habit; earthy to dull luster; silty to gritty texture; laminae or massive structure; black carbonaceous material; scattered very fine grained Tuffaceous sandstone with Tuffaceous matrix, matrix supported; non HCl reaction. Tuffaceous Siltstone (6200' - 6240') = olive gray to light olive gray and light to medium gray; friable to hard; dense to brittle tenacity; splintery or earthy fracture; sub tabular to sub wedgelike cuttings habit; dull to earthy luster; gritty to silty texture; laminar or massive structure; Tuffaceous sandstone, very fine grained, matrix supported, Tuffaceous matrix; no HCl reaction. Tuffaceous Siltstone (6240' - 6285') = olive gray to light olive gray and light to medium gray; friable to hard; dense to brittle tenacity; splintery or earthy fracture; sub tabular to sub wedgelike cuttings habit; dull to earthy luster; gritty to silty texture; laminar or massive structure. Coal / Carbonaceous Siltstone (6285' - 6300') = black to dark gray; brittle to crumbly tenacity; conchoidal to splintery fracture; massive cuttings habit; resinous luster; matte texture; massive structure; correlates with TM-18 coal. Tuffaceous Siltstone (6300' - 6360') = light olive gray to olive gray; friable to firm friable; crumbly to crunchy tenacity; earthy fracture; sub tabular to sub wedgelike cuttings habit; earthy to dull luster; silty to gritty texture; laminae or no structure; carbonaceous material at times, Tuffaceous matrix, grains at times almost lower very fine. Tuffaceous Siltstone (6360' - 6350') = olive gray to light olive gray; friable to firm friable; crunchy to crumbly tenacity; earthy fracture; sub tabular to dull luster; silty to gritty texture; laminar structure; carbonaceous material; silt almost to very fine grains; Tuffaceous matrix. Tuffaceous Sandstone (6350' - 6470') = olive gray to medium gray; grades from and interbedded with dark olive gray Tuffaceous siltstones; lower fine to lower medium grading to very fine and silty tuff; soft mushy tuff matrix support with rare weak crunchy grain support; lithic sub quartzose; subangular to angular; well sorted; noncalcareous. Coal (6470' - 6500') = sub bituminous; blocky to wedgelike to irregular cuttings; dull to occasional resinous Anna 17A 22 luster; silty in part; grades to carbonaceous siltstone; correlates to TM-19. Tuffaceous Siltstone (6500' - 6530') = dark olive gray to very dark gray; soft mushy clayey siltstone to weak crumbly sandy siltstone to dense brittle shaly siltstone; scattered to common carbonaceous microlamina; massive structure predominant; massive to wedgelike cuttings; noncalcareous. Conglomeratic Sand/Tuffaceous Sandstone (6530' - 6650') = olive gray; secondary yellowish gray tuff; moderate salt and pepper appearance; lower medium to lower coarse predominant with common upper coarse to granule and pebble fragments to 6mm and upper fine to upper very fine ; well sorted; spheroidal to subdiscoidal predominant with common very dischoidal to prismoidal; subangular to angular predominant with common very angular and occasional sub round to well rounded in coarser grains; loose grains predominant with soft tuff/silt matrix common to occasional and rare brittle grain supported fragments; 80-90% quartz with dark gray to black volcanic lithics, smoky quartz, reddish brown volcanics, jasper, rose quartz, translucent greenish gray lithics, and chloritized tuff fragments; some micro fractures visible in coarse grains; scattered to abundantly moderately calcareous; interbedded with siltstones as above. Coal (6670' - 6690') = sub bituminous; blocky to irregular fracture; predominantly silty with abundant microlamina; earthy to dull to trace resinous luster; correlates to TM-20. Conglomeratic Sand/Conglomerate (6700' -6785') = olive gray to medium gray; lower fine to lower coarse predominant with common to abundant upper coarse to granule with small pebble fragments to 5mm; well to moderately sorted; subangular to very angular with sub round to round in coarse and granule; loose grains with common to occasional soft tuff/silt matrix; 80% quartz with dark gray to black lithics, reddish brown volcanics, jasper, and chloritized tuff fragments; non to scattered weakly calcareous. Coal (6785' - 6795') = sub bituminous; blocky to irregular; dull to earthy luster; silty; correlates to TM-21. Sand/Tuffaceous Sandstone/Conglomerate (6795' - 6820') = olive gray; secondary yellowish gray tuff; fine to coarse with abundant granule and pebble fragments to 12mm; loose grains predominant with common to abundant soft tuff/silt matrix. Coal (6870' - 6880') = sub bituminous; grades to carbonaceous siltstone; irregular to blocky fracture; correlates to TM-22. Tuffaceous Siltstone (6880' - 6900') = dark olive gray to very dark gray; mushy soft to crumbly to dense friable; silty to clayey; abundantly carbonaceous; massive to subtly bedded structure. Conglomerate/Tuffaceous Sandstone (6900' - 7010') = olive gray to yellowish gray soft lower fine to lower medium grained tuff/silt matrix supported sandstone and olive gray to dark gray upper fine to granule to 6mm pebble fragment loose sand; moderately sorted; subangular to very angular with sub round to round; sub spheroidal to discoidal; quartz predominant with abundant dark gray to black lithics; trace reddish brown volcanics, jasper, and translucent greenish gray lithics; scattered tuff fragments; abundant micro fractures visible in coarser grains; noncalcareous. Coal (7010' - 7045') = black to grayish black; tough to crunchy; sub conchoidal to blocky fracture; wedgelike cuttings; dull with vitreous to resinous luster; matte to mottled texture; laminar structure; common pyritized laminae occurring as thin beds; slight offgassing in many cuttings; low medium grade; correlates with coals TM-23. Tuffaceous Siltstone/Sandstone (7010'- 7140') = olive gray to medium gray with brownish gray hues; dense to crunchy with irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; gritty to granular texture; intergrading with Tuffaceous sandstone that is light olive gray to pale brown and similar to that described above; can be clayey in places; interbedded with sands, carbonaceous shale and coals. Anna 17A 23 Coal (7120' - 7130') = black; tough to crunchy; planar fracture; elongated tabular cuttings; vitreous to sub metallic luster; matte texture; laminar structure; thin beds; slight offgassing in many cuttings; low to medium grade; appears to correlate with TM-24. Tuffaceous Sandstone (7140' - 7230') = medium gray to very pale brown with yellowish hues; lower very fine to upper fine grained; fair to very well sorted; subangular to rounded; moderate to high sphericity; some frosting and polish; firm to easily friable; trace calcite cement; grain supported with some Tuffaceous matrix; occasional carbonaceous laminae; composed of volcanics with lesser amounts of quartz; slightly calcareous; some cuttings exhibit slight stain, pale yellow fluorescence, delayed weak milk cut, but no other hydrocarbon indicators. Coals (7185' - 7290') = black; tough to crunchy; planar to blocky fracture; platy to wedgelike cuttings habit; resinous to vitreous luster; matte texture; thin laminar structure with some pyritization; occur as thin beds at approximately 7190'-7195', 7230'-7235', 7260'-7265', and 7285'-7290' MD; occur with thin to thick beds of Tuffaceous siltstone and sandstone; intergrade to and interbedded with carbonaceous shale; correlates with TM-25 and TM-26. Tuffaceous Siltstone (7170' - 7350') = medium olive to medium gray with light gray and olive hues; brittle to crunchy; irregular blocky fracture; tabular to nodular cuttings; dull earthy luster; clayey to gritty texture; thin to laminar structure; some carbonaceous laminae; intergrading to sandstone as described above and finer Tuffaceous siltstone and shale; interbedded with thin coal, sands carbonaceous shale, rare fine gravels; slightly calcareous in places. Coal (7350' - 7375') = black with reddish hues; tough to brittle; blocky to planar fracture; wedgelike cuttings habit; resinous to dull luster; matte to mottled texture; thin laminae, some oxidized; thin beds in Tuffaceous rocks; some offgassing; correlates with TM-27. Coal (7435' - 7460') = sub bituminous; blocky to irregular to splintery; earthy to resinous to trace vitreous luster; occasionally silty. Tuffaceous Siltstone (7460' - 7530') = olive black to very dark gray; soft crumbly predominant with common dense to shaly; silty to clayey texture; wedgelike to tabular to massive cuttings; massive structure; abundant PDC impact. Coal (7500' - 7510') = sub bituminous; trace weak to moderate offgassing; correlates to TM-28. Tuffaceous Sandstone (7530' - 7595') = olive gray to light brownish gray; upper fine to upper medium grading to very fine volcanics with occasional loose grains and fragments grading to granule; well sorted; spheroidal to sub dischoidal and subprismoidal; subangular to angular; soft tuff/silt matrix support with common to abundant loose grains; massive structure with occasion subtle tuff bedding; 80% quartz/colorless volcanics with gray to black lithics and rare reddish brown volcanics; scattered weakly to moderately calcareous; occasional Tuffaceous, carbonaceous, and shaly siltstone fragments. Coal (7595' - 7600') = sub bituminous; earthy to vitreous; grades to carbonaceous siltstone; correlates to TM-29. Tuffaceous Siltstone/Claystone (7600' - 7680') = olive gray to gray with black and yellowish brown hues; crumbly to pulverulent; irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; clayey to gritty texture; common carbonaceous laminae and dark fines; intergrading to Tuffaceous shale and sandstone; interbedded with coal and carbonaceous shale in places. Coal (7665' - 7675') = black with gray hues; brittle to crunchy; splintery; tabular to wedgelike cuttings; resinous luster; mottled to matte texture; laminar structure with common pyritized laminae; vigorous offgassing; correlates with TM-30. Anna 17A 24 Tuffaceous Sandstone (7680' - 7830') = white to pale brown with yellow and gray hues; upper very fine to lower medium with common coarser grains to fine gravel in places; poor to fair sorted; angular to rounded; very low to high sphericity; common mechanical abrasion surface features; unconsolidated to moderately hard; composed of quartz (70%) and volcanics with trace greenstone; reddish and black lithics; tuff matrix and grain supported varieties; non- to somewhat calcareous; occasional silica and calcite cemented varieties; intergrading to Tuffaceous siltstone and claystone; interbedded with thin coal (TM-32), carbonaceous shale and coarse sand stringers. note: fluorescent mud additives do not permit accurate identification of hydrocarbon indicators in these samples. Coal (7815' - 7822') = black with reddish hues; tough to brittle; splintery; tabular to wedgelike cuttings; vitreous luster; mottled to matte texture; thin laminar structure; oxidized and pyritic laminae common; vigorous offgassing; appears to correlate with TM-33 and TM-33a. Tuffaceous Sandstone (7830' - 7980') = white to pale brown with yellow and gray hues; lower very fine to upper medium with some coarse grains; poor to fair sorted; angular to round; very low to moderate sphericity; common abrasion features; easily friable to unconsolidated with darker gray calcite cemented varieties less common and hard, and abundant Tuffaceous matrix and grain supported varieties more friable; composed of quartz and clear volcanics in roughly equal parts; trace greenstone and red, dark gray volcanics, and black carbonaceous fines; intergrading with Tuffaceous siltstone and shale; occur in thin beds containing thin stringers of sand, coal, and carbonaceous shale; coal stringers correlate with several coal beds predicted between TM-33a and TM-34, but not numbered on projected logs. fluorescent mud additives do not permit accurate identification of hydrocarbons. Tuffaceous Sandstone (7980' - 8100') = white to pale brown with yellow and gray hues; upper very fine to upper medium with some coarser grains; poor to fair sorted; angular to round; very low to moderate sphericity; common abrasion features; easily friable to soft; darker gray cemented variety <5% of sample; composition as above; black carbonaceous laminae common; more greenstone; intergrading and interbedded with finer rocks and sands as above; moderately calcareous. Coal (8060' - 8140') = black with brown hues; dense to crumbly; irregular blocky to splintery fracture; wedgelike to flaky cuttings; metallic to vitreous luster; matte to mottled texture; thin to laminar structure; some offgassing; correlates with TM-34 and TM-35. Tuffaceous Sandstone (8075' - 8115') = olive gray; lower fine to lower medium with occasional coarse to lower granule; spheroidal to subdiscoidal; subangular to angular; soft tuff matrix support predominant; 80% quartz with gray to black lithics and trace jasper, greenish gray lithics, and yellowish gray tuff fragments; scattered weakly calcareous. Tuffaceous Siltstone (8115' - 8200') = dark olive gray to grayish black; silty to very fine sandy siltstone predominant with occasional clayey siltstone; soft crumbly to dense friable with occasional mushy; grades to carbonaceous siltstone with scattered carbonaceous microlamina; noncalcareous; interbedded with weakly calcareous soft Tuffaceous sandstone. Coal (8200' - 8210') = sub bituminous; blocky to irregular; earthy luster predominant with trace resinous and vitreous; silty common. Tuffaceous Sandstone (8210' - 8290') = olive gray to dark gray with brownish gray hue; lower fine to lower medium with upper medium to coarse and scattered very coarse to granule; subangular to angular; sub dischoidal to spheroidal; well sorted predominant; lithic sub quartzose; grades to sandy Tuffaceous siltstone; abundant loose grains; moderately to very calcareous; rare brittle grain supported sandstone fragments. Coals (8290' - 8340') = sub bituminous; blocky to irregular to flaky; silty; thinly bedded; earthy luster with trace resinous; correlate to TM-36 and TM-37. Anna 17A 25 Tuffaceous Siltstone/Claystone (8340' - 8360') = dark olive gray to very dark gray; mushy soft and firm to dense crumbly to friable; wedgelike to irregular to tabular cuttings; massive structure; irregular fracture; silty to clayey texture; grades to carbonaceous siltstone; interbedded with fine to medium sands and grain supported sandstone. Tuffaceous Sandstone (8360' - 8380') = olive gray; lower fine to lower medium grading to very fine volcanics; scattered coarser; soft tuff/silt matrix support with common brittle grain support. Coals (8380' - 8425') = sub bituminous; irregular to blocky; earthy to dull luster; grades to carbonaceous siltstone with carbonaceous microlamina; coal at 8415' correlates to TM-38a. Tuffaceous Sandstone (8425' - 8460') = olive gray; secondary yellowish gray tuff; upper fine to upper medium with scattered to very coarse; well sorted; subangular to angular; lithic sub quartzose; soft matrix support predominant with trace crunchy grain support. Tuffaceous Sandstone (8460' - 8550') = olive gray to pale brown with yellow hues; upper very fine to upper fine with some coarser grained; fair to well sorted; angular to rounded, very low to high sphericity generally increasing inversely to grain size; common signs of mechanical abrasion; hard to soft; some calcite cement; grain supported in tuff matrix; intergrading with Tuffaceous siltstone; interbedded with stringers of carbonaceous shale and occasionally low-medium grade bituminous coal. Tuffaceous Siltstone (8460' - 8610') = dark gray to medium brownish gray; dense to crunchy; irregular blocky fracture; tabular to scaly cuttings habit; dull earthy luster; smooth to granular texture; thin to laminated structure, occasional carbonaceous laminae; common dark fines; intergrades to Tuffaceous sandstone, and interbedded with carbonaceous shale and coals as described above. Tuffaceous Siltstone (8610' - 8700') = dark gray to medium brownish gray; tough to crunchy; irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; smooth to granular texture; thin to laminated structure, occasional carbonaceous laminae; common dark fines; intergrades to Tuffaceous sandstone, and interbedded with carbonaceous shale and occasionally thin coal stringers. Tuffaceous Sandstone (8640' - 8790') = olive gray to pale brown with yellow hues; lower very fine to upper medium coarsening downward; poor to well sorted; angular to rounded, very low to high sphericity; common signs of mechanical abrasion; hard to unconsolidated with some calcite cement; grain supported with common tuff matrix; intergrading with Tuffaceous siltstone; interbedded with stringers of carbonaceous shale, coarse sands, and medium grade bituminous coals. the coals in this zone are typically black; tough to crunchy; splintery; resinous with matte and mottled texture; thin laminar structure; exhibit no to little; offgassing, are low to medium grade bituminous and do not correspond to any numbered deposit. Coal (8770' - 8830') = black with dark gray hues; tough to crunchy; irregular blocky to planar fracture; tabular to wedgelike cuttings habit; vitreous to resinous luster; mottled texture; thin laminae; slight to moderate offgassing; rocks; coal at 8820'-8825' MD correlates coal at 8820'-8825' MD correlates with the Tyonek C2-A marker. These coals occur in thin beds with Tuffaceous sandstone and or siltstone as above. Coal (8850' - 8890') = black with light brown hues; tough to crunchy; irregular blocky to sub conchoidal fracture; tabular wedgelike to flaky cuttings; resinous to vitreous; mottled to matte texture; laminar structure; slight to moderate offgassing; two coals are interbedded with Tuffaceous siltstone as sandstone as described above; they correlate with the C-2A and C-2B markers and are approximately 5' to 10' thick. Tuffaceous Siltstone (8890' - 8925') = dark olive gray to grayish black; soft crumbly siltstone to mushy hydrophilic clayey siltstone with dense brittle to moderately hard blocky to tabular shaly; blocky to massive cuttings predominant; associated sands fine to medium grained. Anna 17A 26 Coals (8925' - 8980') = sub bituminous; blocky to irregular with occasional conchoidal fracture; wedgelike to blocky to weakly splintery cuttings; silty in part with abundant micro laminated carbonaceous siltstone; earthy to resinous with scattered vitreous micro banding; scattered weak offgassing. Tuffaceous Siltstone (8980' - 9060') = olive black to dark brownish gray soft crumbly to mushy Tuffaceous siltstone and dark gray to dark olive gray dense friable to moderately hard brittle shaly siltstone; silty to clayey and sandy texture; wedgelike to weakly tabular to massive cuttings; massive structure predominant with common carbonaceous microlamina; scattered fine to medium grained sand and very fine to fine grained grain supported calcareous Tuffaceous sandstone fragments; noncalcareous overall Tuffaceous Sandstone/Sand (9100' - 9290') = dark olive gray to dark gray; salt and pepper appearance; medium grained with scattered coarse to granule and fine grains; well sorted; spheroidal to subdiscoidal and subprismoidal; subangular to angular with sub round coarse; loose grains predominant with abundant soft tuff/silt matrix support and occasional to common brittle grain supported fragments; 75% quartz with gray to black lithics and trace reddish brown volcanics, pinkish gray lithics, jasper, and chlorite; non to scattered moderately calcareous; 15-30% bright to moderate yellow sample fluorescence, increasing downward; rocks coarsen downward and become unconsolidated and in places consist of conglomeratic sands and occasionally fine gravels; intergrading to thin siltstone in places; interbedded with thin coal and carbonaceous shale stringers in places; selected sandstone cuttings in this interval observed in UV light have bright yellow fluorescence, pale to bright yellow cut fluorescence, instantaneous pale to strong milk cut, and residual milk cut; no visible cut or odor were observed, but some stain was observed on cuttings; light oily sheen and foam was observed over shakers; the sands correlate to C-5A and C5B. Tuffaceous Siltstone (9250' - 9340') = medium to dark gray with brownish hues; dense to pulverulent; irregular blocky fracture; tabular to nodular cuttings; dull earthy luster; gritty to granular, textures; thin structure, some laminae; intergrading with sandstones; interbeds with carbonaceous shale, sand and coal. Coal (9300' 9310') = dark brownish black to black; tough to brittle; splintery fracture; flaky to fine wedgelike cuttings; resinous luster; matte texture; slight offgassing; correlates with C-6 coal marker; thin stringers of similar coal occur to depths of 9330'. Tuffaceous Siltstone (9300' - 9390') = pale brown to dark brownish gray with dark gray hues; crunchy to pulverulent; irregular blocky fracture; tabular to nodular cuttings habit; dull to earthy luster; clayey to gritty; thin to laminated structure; intergrading with thin Tuffaceous sandstone; interbedded with thin coal stringers, sand, and carbonaceous shale. Tuffaceous Siltstone (9390' - 9445') = dark olive gray to very dark gray; soft crumbly to weakly dense brittle; irregular cuttings with common bit impact; massive structure predominant; common micro laminated carbonaceous cuttings; silty to sandy texture; scattered dense shaly cuttings; interbedded with irregular to blocky earthy to resinous coals. Tuffaceous sandstone (9450' - 9490') = olive gray with brownish gray hue; upper fine to upper medium grading to very fine volcanics with scattered coarse to granule; soft tuff/silt matrix predominant with occasional crunchy grain support; subangular; moderate to low sphericity; 80% quartz with gray to black lithics with rare jasper and greenish gray lithics; noncalcareous. Conglomeratic sand (9520' - 9595') = dark gray to olive gray; upper fine to upper very fine predominant grading to coarse to 5mm pebble fragments; well sorted; subangular to very angular; subdiscoidal to spheroidal; loose grains predominant with scattered tuff/silt matrix; 75% quartz; common dark gray to black lithics; trace greenish gray and reddish brown lithics; rare muscovite, rose quartz, and jasper; common dispersed strong reaction to HCl in part from calcite mud additive; rare dull gold spot fluorescence; no other indicators. Tuffaceous sandstone (9600' - 9690') = olive gray to dark gray with light brownish gray tuff; fine to Anna 17A 27 medium predominant grading to 7mm pebble and very fine volcanics; soft silt/tuff matrix support grading to sandy tuffaceous siltstone and soft calcareous sandy/silty tuff; scattered brittle grain supported calcareous and siliceous fine grained sandstone fragments; compositionally as above; scattered very dull gold fluorescence; no cut; pale yellow residual cut fluorescence on some cuttings. Tuffaceous sandstone (9690' - 9780') = very pale brown to gray with olive hues; lower very fine to upper medium with some coarser grains; poor to fair sorted and subangular to subrounded; low to moderate sphericity; matrix and grain supported varieties; common to abundant tuff and silt matrix; composed of quartz and volcanics; calcareous in part; thin fissile structure; easily friable to hard; scattered dull gold fluorescence; pale instant cut; pale yellow residual cut fluorescence seen on some cuttings; no residual cut or other hydrocarbon indicators. Tuffaceous siltstone (9780' - 9870') = dark olive gray with dark gray; soft crumbly to weakly mushy; trace weakly shaly; silty predominant with occasional clayey; non-cohesive and non-adhesive predominant; massive to tabular cuttings with common PDC impact layering; massive structure; grades to carbonaceous siltstone with scattered carbonaceous microlamina; scattered fine to very coarse sand; rare grain supported fine grained sandstone fragments. Tuffaceous siltstone (9870' - 9960') = dark olive gray to medium gray; soft crunchy to pulverulent; irregular blocky fracture; fine tabular to nodular cuttings; dull earthy luster sometimes sparkling where very gritty; clayey to gritty textures; thin sometimes fissile structure; intergrading with tuffaceous shale and sandstone; trace ash; interbedded with thin carbonaceous shale beds and occasional coal stringers. Tuffaceous sandstone (9930' - 9990') = pale brown to medium olive gray; lower very fine to upper medium grain with some coarser; poor to fair sorted; subangular to subrounded; low to moderate sphericity; some mechanical abrasion; most silty tuffaceous matrix supported; friable to soft; calcareous in part; 20% dull yellow gold sample fluorescence; pale instantaneous cut; residual milk cut; also yellow- green cut fluorescence in firmer cuttings taken below 9960' MD. Conglomeratic sand/tuffaceous sandstone (9990' - 10100') = olive gray to dark gray; salt and pepper appearance; scattered brownish to yellowish gray tuff; upper fine to upper medium predominant with abundant coarse to 5mm pebble fragments; grades to very fine; moderately to locally well sorted with unsorted very fine volcanics weathered from tuff matrix; subangular to angular with very angular shards and scattered sub round granule; subdiscoidal to spheroidal predominant with common discoidal and prismoidal; loose grains predominant with common to rare tuff/silt matrix and trace grain support; 70% quartz with gray to black lithics/mafics, opaque reddish brown volcanics and jasper, greenish gray lithics, clastic coal, and reworked ash/tuff fragments; very to moderately calcareous; 10-40% dull to moderate yellow to gold sample fluorescence; diffuse moderate to weak milky cut; moderate yellow to gold residual cut fluorescence; no visible cut; no visible residual cut; trace possible stain; trace weak odor. Tuffaceous sandstone (10100' - 10230') = olive gray to pale brown with light and dark salt and pepper hues; lower very fine to lower medium grained with some coarser; fair to well sorted; subrounded to rounded; low to high sphericity; some polish and frosting; unconsolidated to easily friable; matrix supported with ash/tuff matrix; slightly calcareous; composed mostly of quartz (60%) and light and dark volcanics; intergrading with tuffaceous siltstone; interbedded with thin carbonaceous shale; dull gold fluorescence; pale-strong milk cut; weak straw to clear visible cut; milky yellow white cut fluorescence; 10- 40% sample fluorescence; show improves downward. Tuffaceous siltstone (10230' - 10330') = dark olive gray to olive black; secondary brownish gray; soft crumbly to mushy with occasional shaly dense; massive to wedgelike cuttings; sandy siltstone grading to silty claystone; grades to and interbedded with carbonaceous siltstone; non-adhesive; non-cohesive; massive structure with trace carbonaceous microlamina; scattered soft tuffaceous sandstone; trace grain supported crunchy sandstone; occasional to common fine to very fine sand with rare medium to coarse; rare mica. Anna 17A 28 Coal (10325' - 10330') = black to olive black; silty sub bituminous grading to micro laminated carbonaceous siltstone; irregular to blocky fracture. Tuffaceous siltstone/claystone (10330' - 10400') = dark olive gray silty claystone to sandy siltstone with light brownish gray silty ash tuff fragments; soft crumbly to mushy with scattered shaly; non-adhesive; non- cohesive; massive structure and cuttings; grades to fine to medium grained soft to crunchy tuffaceous sandstone in lower interval. Tuffaceous sandstone (10400' - 10480') = light to medium gray with brown and olive hues; lower very fine to upper fine with some coarser; fair to well sorted; subrounded to round; mod to high sphericity; soft to easily friable; matrix supported; tuff/ash and partly calcareous silt matrix; composition quartz and volcanics; intergrading to gritty tuffaceous siltstone; coarsening down; interbedded with carbonaceous shale, also coarse sand, ash, and coal in places; patchy dull gold fluorescence; some stain, faint odor in places; pale residual milk cut and yellow cut fluorescence seen on only a few cuttings. Tuffaceous siltstone (10480' - 10560') = light olive to dark brownish gray; crumbly to pulverulent; irregular blocky fracture; tabular to wedgelike cuttings; dull earthy luster; gritty to clayey texture; thin laminar to fissile structure; intergrading with tuffaceous sandstone; interbedded with carbonaceous shale, thins sands and coals in places. Tuffaceous sandstone/claystone (10560' - 10670') = pale gray to pale yellow with slight gray and pale brown hues. lower medium to upper fine to upper medium grained; sub spheroidal to sub discoidal; sub angular to angular to sub rounded; moderate to poor sorting; dominated by clear to translucent quartz; minor amount of dark lithics; grain supported; tuff/ash matrix; calcareous; the claystones are very dark blackish gray to brown with grayish hues moderate induration; blocky to planar fracture; platy to tabular cuttings habit; sandstone covered in 80% dull yellow fluorescence; very weak bluish white instantaneous cut; no odor. Tuffaceous sandstone/claystone (10670' - 10755') = dark brown to medium brown with dark grayish hues; poor consolidation to unconsolidated to trace firmly friable; upper fine to lower medium to lower fine; sub angular to sub rounded; sub spherical to sub discoidal; poor to moderate sorting; grain supported; tuff/ash matrix; slightly calcareous; claystones are medium brown do dark grayish brown; poor to moderate induration; blocky to occasionally planar fracture; clayey to silty texture; trace scattered fluorescence; no cut or odor. Tuffaceous claystone/sandstone (10755' - 10880') = dark medium gray to dark brownish medium gray; crumbly to slightly tough; poor to moderate induration; blocky to planar fracture; platy to tabular cuttings habit; silty to clayey texture; dull to earthy to waxy luster; interbedded with silt and sandstone; carbonaceous lamina common too; poor cohesiveness and adhesiveness; the sandstone is pale yellowish brown; poorly consolidated; lower medium to upper fine grained sub discoidal to sub spheroidal; sub angular to sub rounded; grain supported; ash/tuff matrix; calcareous; dark lithics uncommon; scattered bright white fluorescence on 30% of the clasts; very slow milky white cut; pale yellowish white residual cut; no odor. Coal (10880' - 10910') = black to dark brownish gray; tough to crunchy; planar to splintery fracture; tabular to wedgelike cuttings habit; resinous to dull luster; mottled to matte texture with thin laminae; occur as thin beds intergraded with carbonaceous shale; interbedded with tuffaceous siltstone, siltstone and claystone; lignitic to sub bituminous; no offgassing seen. Tuffaceous sandstone/siltstone (10880' - 10990') = dark gray to very pale brown, darker in finer specimens; lower very fine to upper medium; poor to fairly sorted; angular to rounded; low to high sphericity; common polish; hard to soft; trace cement; grain supported; up to 30% silt/tuff matrix, some floating fabric; 10% dull gold to yellow sample fluorescence; no odor; very weak delayed pale residual cut and pale yellow cut fluorescence in only a few specimens; no other hydrocarbon indicators. Anna 17A 29 Coal (10950' - 11010') = black; brittle to crunchy; planar to sub conchoidal fracture; tabular to wedgelike cuttings habit; metallic to vitreous luster; matt to mottled texture; laminar structure; low medium grade bituminous; offgassing common; thin beds intergrading to dark carbonaceous shale; interbedded with tuffaceous rocks as described above. Tuffaceous sandstone/siltstone (11010' - 11180') = pale yellowish white to very pale gray; soft to unconsolidated; upper fine to lower medium with lower fine to upper very vine being common; sub rounded to sub angular; sub spheroidal to sub discoidal; poor to moderate sorting; grain supported in a tuff/ash matrix; calcareous; interbedded with carbonaceous lamina and tuff siltstones; occasional; the siltstones are typically dark gray with blackish hues to dark medium brown; slightly tough to crumbly; blocky; tabular to occasionally platy cuttings habit; silty to clayey texture; grades from a sandy siltstone to a silty sandstone; interbedded with thin layers of clay and ash; also carbonaceous lamina; <5% sample fluorescence; no cut no odor. Tuffaceous siltstone/sandstone (11180' - 11250') = brownish gray to dark grayish black; crumbly to semi tough; blocky to irregular fracture; tabular cuttings habit; dull to earthy luster; silty to clayey texture; claystone common with interbedded carbonaceous lamina; sandstones are soft; lower medium to upper fine grained; sub angular to sub rounded; moderate to poor sorting; sub discoidal to sub spherical; grain supported; ash/tuff matrix; calcareous; no hydrocarbon indicators. Tuffaceous sandstone = (11250' - 11355') = pale brownish gray to light gray with pale yellowish orange hues; soft to unconsolidated; lower medium to upper fine to lower fine; moderate to poor sorting; sub angular to sub rounded; sub discoidal to sub spherical; borders on matrix supported; tuff/ash matrix; slightly calcareous; minor amounts of dark grayish black siltstone; semi tough; irregular fracture; platy to tabular cuttings habit; dull to slightly vitreous luster; samples get sandier and unconsolidated down through the interval; coal observed throughout the samples; matte black; flaky; sub bituminous; samples contaminated with mud product and display grain fluorescence across the latter samples. Dull yellow fluorescence on <5% of the samples; no cut or odor. Tuffaceous siltstone = (11355' - 11440') = medium gray to olive with pale brown hues; dense to crumbly; irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; granular to gritty; thin structure with common carbonaceous laminae; intergrading with tuffaceous claystone and sandstone; coarsening downward; interbedded with thin carbonaceous shale and coal beds. Coal (11390' - 11430') = black to dark brownish gray black; tough to brittle; planar fracture; tabular to wedgelike cuttings; dull to resinous luster; matte texture; thin laminar structure; inter- grading with carbonaceous shale; thin beds interbedded with tuffaceous rocks. Sand/tuffaceous sandstone (11430' - 11540') = pale yellowish gray to pale grayish white; unconsolidated to soft; lower medium to upper fine to lower fine to upper medium; poor sorting; sub angular to angular to occasional sub rounded; sub spherical to sub discoidal; poor sorting; impact abraded quartz; minor amount of 2-4mm quartz grains present; tuffaceous sandstone is grain supported; tuff/ash matrix; slightly calcareous; carbonaceous shale siltstone and tuffaceous claystone all common but not abundant; 90% whitish gold; pale gold instantaneous cut; no odor. Coal (11540' - 11600') = matte black to black with dark brown hues; semi tough to brittle and crumbly; planar fracture; platy to flaky to tabular cuttings habit; dull to resinous to waxy luster; trace off gassing; interbedded with carbonaceous shale and tuffaceous material. Sand/tuffaceous siltstone/sandstone (11600' - 11705') = pale yellowish brown to light medium brown with light blackish hues; unconsolidated to soft to occasionally friable; lower medium to upper fine with upper medium to lower coarse being common; sub angular to angular; sub discoidal to sub spherical; poor sorting; sandstones are typically grain supported; quartz dominated; tuff/ash matrix to an occasional calcareous matrix; sandstones are often interbedded with carbonaceous shale lamina; siltstones are typically semi tough to crumbly and brittle; dark medium gray with bluish hues; blocky fracture; tabular Anna 17A 30 cuttings habit; silty to gritty texture; trace bright goldish white on <5% of the samples; no cut or odor. Tuffaceous sandstone (11705' - 11740') = light medium gray to light gray with pale yellow hues; unconsolidated to soft; sub angular to angular; lower medium to upper fine; sub discoidal to spherical; poor to moderate sorting; no hydrocarbon indicators. Coal (11740' - 11760') = matte black to dark grayish black; crumbly to brittle; wedgelike cuttings habit; irregular fracture; metallic to resinous luster. Tuffaceous sandstone (11740' - 11870') = grey to grayish brown to dark greenish brown; dominantly upper very fine to upper fine, occasional lower and upper coarse; well to moderately sorted; angular to subrounded; moderate sphericity to very discoidal; soft to easily friable, unconsolidated; grain supported with 10-40% tuff matrix; dominantly quartz with occasional to moderate carbonaceous material inclusions, green stone, volcanic glass, trace conglomerates increasing to 5% by 11860'. 0-5% dull yellow fluorescence, only 11850' had slow to moderate, weak, milky white cut, some black foam and free oil sheen on shakers. Tuffaceous sandstone (11870' - 11980') = reddish grey to dark reddish grey, light light grey to pinkish grey, grayish brown to darkish brown; dominantly lower fine to upper medium grains, occasional lower very fine and some lower and upper coarse, trace to 10% conglomerate; moderate sorted to well sorted at lower depth; dominant sub- angular to subrounded, secondary angular and some well rounded; moderate sphericity to moderate discoidal; very friable to soft and some slightly firm (only darker colored cuttings), abundant loose grains; grain supported with tuff matrix, increasing tuff matrix with depth; before 11950' abundant carbonaceous inclusions with trace mica, green stone, and carbonaceous siltstone; after 11950, very few inclusions -- dominant quartz with only tuff matrix. Conglomeratic sand/tuffaceous sandstone (11980' - 12080') = dark medium gray to medium gray with brownish hues; moderate array of grain sizes with upper fine to upper medium being the most abundant; 2-8mm quartz and volcanic grains common; occasionally impact abraded; poor sorting overall with some well sorted sandstone clasts; grains are sub spherical to sub discoidal; sub angular to sub rounded to angular; sandstones are typically grain supported; tuff/ash matrix; slightly calcareous; occasional siltstone with embedded carbonaceous shale; bright goldish white fluorescence on 30% of sample; extremely slow pale white cut; trace oil stains on grains; no odor. Conglomeratic sand (12080' - 12220') = medium gray to light medium gray with pale brown hues; unconsolidated to trace firmly friable clasts; lower medium to upper fine with lower coarse to upper very fine grains common, conglomerate sand cuttings up to 3 mm; subangular to subrounded; sub discoidal to sub prismoidal; abundant frosting and impact abrasion; individual grains translucent, abundant dark grey, light greenish grey, and light red. Tuffaceous sandstone (12200' - 12250') = grey to reddish grey; upper very fine to upper fine, increasing to lower medium with depth; very well to moderately sorted; rounded increasing to subangular; highly spherical grading to moderately discoidal; hard to very friable, occasional abundant loose grains; grain supported with tuff/ash matrix; darker samples include abundant carbonaceous material, some pyrite, and green stone; 30% moderate gold fluorescence; extremely slow milky white cut; moderate gold residual cut; no odor; no visible staining. Conglomeratic sand (12250' - 12340) = light medium gray to medium gray with pale brown hues; lower medium to upper fine to lower coarse to upper very fine; poor sorting; angular to sub angular to occasionally sub rounded; discoidal to sub spherical; unconsolidated to trace firmly friable clasts; grain supported; 2-10mm sized grains common; impact abraded grains common; fluorescence ranges from 10- 40%; very slow pale white cut; moderate gold residual ring; trace odor. Tuffaceous sandstone (12250' - 12450') = light grey with slight light red; upper very fine to lower medium, rare coarse grains; moderate sorting; sub rounded to sub angular; highly spherical to sub Anna 17A 31 discoidal; larger grains exhibit frosting/impact abrasion; dominant hard to firm, occasional very friable and rare very hard; grain supported with dominant tuff/ash and some silt matrix; include some pyrite, green- stone, trace shale at 12450'+; some clasts stained green; 12320'-12450' have 5 - 10% dull to mildly bright yellow mineral fluorescence with very slow weak cloudy milky yellow/blue cut and dull yellow/orange residual ring cut, slight dark brown oil stain and no odor, mild oily sheen on shakers. Conglomeratic sand (12450' - 12532') = light medium gray to pale brown with grayish hues; unconsolidated; lower medium to upper fine; 5-20% fluorescence with slow milky to pale white cut. Tuffaceous sandstone (12533' - 12620')= greenish grey to dark greenish grey; lower coarse to upper very fine, dominant upper fine to upper medium; poor sorting; sub angular to sub rounded, some angular and well rounded; highly discoidal to some spherical; very hard to moderately hard, some slightly friable and abundant loose sand grains; grain supported 90% with tuff/ash matrix; 90 - 80% quartz, pale green, grayish green, light red grains; occasional pyrite, carbonaceous material, and green stone. Tuffaceous sandstone (12620' - 12710') = light medium gray to medium gray with a pale greenish hue; unconsolidated to soft to trace moderately hard; lower medium to upper fine with lower coarse to lower very fine grains being common; sub angular to sub rounded to angular; poor to moderate sorting; sub spherical to sub discoidal; tuff/ash matrix; grain supported to trace matrix supported in the harder clasts; slightly calcareous; 2-8mm grains common in upper section; commonly impact abraded quartz and dark volcanics; sorting and grain size stabilizes further down the interval; dull gold fluorescence on <5% of the sample; x-slow to slow dull white cut; very pale gold residual cut; no odor. Tuffaceous sandstone (12710' - 12900') = bluish grey to reddish grey; lower very fine to upper fine; well sorted, occasional upper medium grains; moderate to well rounded to subangular; very high and occasional moderate sphericity; very friable and rare slightly firm, trace hard (hard contains less matrix and is green and has slight larger grains); tuff/ash matrix supported; <3% dull yellow fluorescence, very slow, mild blue/white cloudy cut with minimal residual cut; no odor; decreasing fluorescence with depth. Shale carbonaceous shale (12800' - 12900') = 3 - 5% dark grey / dark reddish grey; tough and slightly brittle; splintery to slightly blocky to platy fracture; tabular / nodular cutting habit; dull / earthy and mildly greasy luster; smooth texture; fissile and striated structure; occasionally interlaced with highly carbonaceous shale/coal - at interface sometimes crenulated. Tuffaceous sandstone (12900' - 12940') = medium gray to light brownish gray; soft to unconsolidated; lower medium to upper fine to lower coarse; trace 2-8mm grains; poor to moderate sorting; sub spherical to sub discoidal; baro-trol mud product common; no fluorescence; x-slow weak white cut; very pale gold residual cut; no odor. Tuffaceous sandstone(12940' - 13100') = medium grey to light brownish grey; lower very fine to upper fine grains; well sorted; dominant sub round to round, occasional subangular; highly spherical, occasional sub discoidal; very friable, abundant loose sand grains; tuff/ash matrix supported; quartz sand grains with occasional abundant micro carbonaceous material and some volcanic glass <1 mm; less than 2% dull yellow fluorescence, slow, weak blue/white cut, faint oil sheen on screen, grades to lower very fine grains with depth with siltier matrix. Tuffaceous sandstone/conglomeratic sand (13100' - 13120') = medium gray to dark medium gray with pale brown hues; unconsolidated to soft to trace hard; poor sorting; lower coarse to upper fine to upper very fine grained; sub rounded to sub angular; sub spherical to sub discoidal; grain supported by tuff/ash matrix; moderately calcareous; variety of secondary minerals including green stone, feldspar, carbonaceous shale and various other dark lithics; semi tough dark brown siltstone clasts common; good induration; 15% moderate to dull gold fluorescence; x-slow pale bluish white cut; pale orangish gold residual cut; trace staining; no odor. Carbonaceous shale (13155' - 13230') = dark reddish brown to reddish black to black; soft to moderately Anna 17A 32 firm; brittle to crumbly; poorly indurate; irregular grading to blocky and slightly conchoidal fracture; massive grading to slightly platy/blocky cutting habit; earthy grading to vitreous luster; silty grading to smooth texture; massive structure, sometimes interlaced thin bedding of carbonaceous shale and coal; no visible offgassing; increase oil in mud report. Tuffaceous sandstone/conglomeratic sand (13230' - 13310') = medium gray to dark medium gray with pale brown and green hues; unconsolidated to soft to trace firm clasts; lower medium to upper fine to lower coarse; sub angular to angular; sub discoidal to sub spherical; poor to moderate sorting; tuff ash matrix; grain supported; partially calcareous; quartz dominated with carbonaceous shale, green stone and other dark lithics common; well indurated blackish gray siltstone semi common; 25% sample fluorescence; moderate streaming cut fluorescence; pale straw residual cut and milky yellow residual fluorescence. Tuffaceous sandstone/conglomeratic sand (13310' - 13420') = medium gray to bluish grey to weak red; dominant upper very fine to lower medium grains, coarse up to 2 mm conglomerate pieces; poor to moderate sorting amid conglomerate sands; well rounded to some sub angular; high to moderate sphericity; very friable to slightly firm; abundant loose grains (of dominant sizes), bluish green tuffaceous sandstone moderate to very hard 1-2%; grain to matrix supported; tuff/ash matrix; sandstone includes loose micro carbonaceous material, green stone, siltstone; occasional silty matrix and some pyrite; 10- 25% dull yellow mineral fluorescence; weak clouding blue/white cut; pale straw ring cut; no odor. Conglomeratic sand (13420' - 13520') = medium gray to dark gray with pale brown and green hues; unconsolidated to trace moderately hard clasts; angular to sub angular; upper coarse to upper fine; poor sorting; sub discoidal to sub spherical; 2-8mm clasts common; impact abraded clasts seen throughout; quartz dominated; greenstone, carbonaceous shale, siltstone and other dark lithics are common; grain supported; minor amount of ash/tuff material; 20-25% sample fluorescence; moderate to fast streaming milky white cut; brown to pale amber residual cut; trace quartz light brown staining; no odor; no free oil observed. Conglomeratic sand (13520' - 13580') = medium gray to light medium gray with brown and green hues; unconsolidated; lower coarse to upper fine grained; sub angular to angular; sub discoidal to sub spherical; 40-50% moderate to bright goldish white fluorescence; very slow dull milky white cut; no odor. Conglomeratic sand (13580' - 13700') = light greenish grey to dark greenish grey; upper very fine to upper coarse grains; poor sorting; well rounded to sub angular; dominant highly spherical, secondary highly discoidal; unconsolidated, tuffaceous sandstones very friable; individual grains mostly translucent and opaque white, occasional light red and pale to dark green; quartz mineral fluorescence diminished from 13650 to td with <5%, cut stopped 13360' 10-25% dull yellow mineral fluorescence, slow, weak, pale blue/white cloudy cut; pale straw/gold fluorescence ring cut, no visible residual cut, very faint odor weak dark brown oil sheen on shakers. Anna 17A 33 3.3 Sampling Program Operator: Hilcorp Alaska, LLC (Hilcorp Energy Company) Well Name: Anna 17A Field: Granite Point Field – Hemlock Oil Pool County:Kenai Borough State: Alaska – Offshore Cook Inlet – Waters of the United States Company Representatives: Shane Hauck, James Sweetsir, Sloan Sunderland, Richard Rumley Location: Surface Coordinates 794' FNL, 603' FEL, Sec 12, T10N, R12W, SM, AK Ground Elevation 0’ (at MSL) Rotary Table Elevation 121’ AMSL Classification:Sidetrack/Production Well API #: 50-733-20311-01-00 Total Depth 13,670 MD/11,297’ TVD Total Depth Formation: Hemlock Total Depth Date: January 02, 2014 Logging Geologists: James Foradas, Greg Hammond, Josh Dubowski, Dylan Muller Sample Catchers: Dean Kekaualua, Dickey Hudgins, Ben Calo The sampling program specified by the Well Site Geologist called for the collection of two sets of washed and dried reference samples beginning at 3314’ MD. The intervals varied with depth and sampling extended from the onset of sampling to TD for each type. The resulting number of sets, sampling intervals and distribution of each sample is shown below. Sets Type and Purpose Interval Frequency Distribution 2 Washed and Dried Reference Samples 3314’ – 10,560’ 11,400’ – 13,670’ 30’ Interval 10’ Interval Jacob Dunston/Matt Frankforter Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage, AK 99508 1 Wet Reference Samples 13,150’ – 13,360’ 10’ Interval Jacob Dunston/Matt Frankforter Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage, AK 99508 Note: All sample sets released to rig expediter for shipment. Anna 17A 34 4 DRILLING DATA 4.1 Surveys MD (ft) Incl (°) Azim True (°) TVD (ft) VSEC (ft) NS (N/S ft) EW (E/W ft) DLS (°/100ft) Closure (ft) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 N/A 0.00 19.00 0.00 0.00 19.00 0.00 N 0.00 E 0.00 0.00 0.00 119.00 1.00 168.00 118.99 0.51 S 0.85 E 0.18 1.00 0.87 219.00 1.50 224.00 218.97 2.34 S 2.65 W 0.55 1.25 2.70 319.00 2.00 217.00 318.93 5.38 S 4.98 W 2.51 0.54 5.58 419.00 2.25 219.00 418.86 9.08 S 7.90 W 4.79 0.26 9.24 519.00 2.17 221.00 518.78 12.94 S 10.86 W 7.27 0.11 13.07 619.00 2.25 228.00 618.71 16.78 S 13.60 W 9.97 0.28 16.86 719.00 2.25 202.00 718.64 20.58 S 16.73 W 12.16 1.01 20.69 819.00 4.00 162.00 818.49 24.18 S 21.87 W 11.82 2.70 24.86 919.00 4.75 151.00 918.20 27.28 S 28.81 W 8.74 1.12 30.11 1019.00 4.50 152.00 1017.88 29.99 S 35.90 W 4.89 0.26 36.23 1119.00 3.75 150.00 1117.62 32.36 S 42.19 W 1.41 0.76 42.21 1219.00 3.25 150.00 1217.43 34.26 S 47.48 E 1.64 0.50 47.51 1319.00 2.75 148.00 1317.29 35.81 S 51.97 E 4.33 0.51 52.15 1419.00 2.25 152.00 1417.20 37.15 S 55.73 E 6.52 0.53 56.12 1519.00 2.00 156.00 1517.13 38.54 S 59.06 E 8.15 0.29 59.62 1619.00 1.50 163.00 1617.08 39.93 S 61.91 E 9.25 0.54 62.59 1719.00 1.75 166.00 1717.04 41.46 S 64.64 E 10.00 0.26 65.41 1819.00 1.50 170.00 1817.00 43.13 S 67.41 E 10.60 0.27 68.24 1919.00 1.50 198.00 1916.97 45.13 S 69.95 E 10.42 0.73 70.72 2019.00 2.50 186.00 2016.91 48.10 S 73.36 E 9.79 1.08 74.01 2119.00 5.45 181.00 2116.66 53.46 S 80.28 E 9.48 2.97 80.84 2219.00 6.17 167.00 2216.15 60.14 S 90.26 E 10.60 1.58 90.88 2319.00 7.00 141.00 2315.51 64.20 S 100.24 E 15.65 3.07 101.45 2419.00 8.50 137.00 2414.59 65.83 S 110.38 E 24.52 1.59 113.07 2519.00 10.25 137.00 2513.25 67.28 S 122.29 E 35.63 1.75 127.38 2619.00 12.50 137.00 2611.28 69.05 S 136.71 E 49.08 2.25 145.26 2719.00 15.00 138.00 2708.41 71.40 S 154.25 E 65.12 2.51 167.43 2819.00 17.75 139.00 2804.34 74.67 S 175.37 E 83.79 2.76 194.36 2919.00 20.00 139.00 2898.96 78.69 S 199.79 E 105.01 2.25 225.70 3019.00 20.50 139.00 2992.78 82.98 S 225.91 E 127.72 0.50 259.51 3119.00 20.25 138.00 3086.52 87.00 S 251.99 E 150.78 0.43 293.65 3219.00 19.83 138.00 3180.47 90.66 S 277.45 E 173.71 0.42 327.35 3319.00 19.25 137.00 3274.71 93.95 S 302.11 E 196.31 0.67 360.29 3419.00 18.83 135.00 3369.24 96.30 S 325.58 E 218.96 0.78 392.36 3509.00 18.25 135.00 3454.57 97.87 S 345.82 E 239.20 0.64 420.48 3533.00 18.00 136.25 3477.38 98.35 S 351.15 E 244.42 1.93 427.84 3578.91 17.09 140.19 3521.15 99.87 S 361.46 E 253.64 3.26 441.57 Anna 17A 35 MD (ft) Incl (°) Azim True (°) TVD (ft) VSEC (ft) NS (N/S ft) EW (E/W ft) DLS (°/100ft) Closure (ft) 3675.01 16.84 148.77 3613.08 105.96 S 384.21 E 269.90 2.62 469.54 3771.27 16.29 157.56 3705.36 115.87 S 408.62 E 282.29 2.66 496.64 3867.91 17.68 166.20 3797.80 130.03 S 435.40 E 290.96 2.98 523.67 3889.83 17.81 168.10 3818.68 133.88 S 441.91 E 292.45 2.71 529.92 3964.29 17.29 174.89 3889.68 148.17 S 464.08 E 295.78 2.84 550.32 4060.34 17.05 177.86 3981.45 168.03 S 492.37 E 297.58 0.95 575.31 4156.68 17.12 174.37 4073.54 187.77 S 520.60 E 299.50 1.07 600.60 4253.48 17.02 176.29 4166.08 207.31 S 548.91 E 301.81 0.59 626.41 4349.55 16.98 176.74 4257.95 227.05 S 576.95 E 303.52 0.14 651.91 4446.25 18.02 182.71 4350.18 248.61 S 605.99 E 303.62 2.14 677.79 4542.80 18.36 184.52 4441.91 272.28 S 636.06 E 301.71 0.68 703.99 4638.61 18.33 184.63 4532.85 296.27 S 666.12 E 299.31 0.05 730.28 4735.25 18.35 185.25 4624.58 320.57 S 696.42 E 296.69 0.20 756.98 4829.24 18.27 185.88 4713.81 344.37 S 725.81 E 293.82 0.23 783.02 4925.96 18.03 185.87 4805.72 368.75 S 755.78 E 290.74 0.25 809.77 5022.63 18.00 187.63 4897.65 393.20 S 785.46 E 287.23 0.56 836.33 5119.44 17.96 186.92 4989.73 417.80 S 815.11 E 283.44 0.23 862.98 5215.87 17.71 187.42 5081.53 442.08 S 844.41 E 279.76 0.30 889.55 5312.23 17.54 184.84 5173.37 465.75 S 873.41 E 276.64 0.83 916.18 5409.10 16.86 181.51 5265.91 488.11 S 902.00 E 275.04 1.24 943.00 5502.70 15.95 179.34 5355.69 507.93 S 928.43 E 274.83 1.17 968.25 5601.64 15.57 182.32 5450.92 528.19 S 955.29 E 274.45 0.90 993.93 5697.93 14.25 183.30 5543.96 547.42 S 980.04 E 273.24 1.40 1017.41 5794.93 13.87 178.35 5638.06 565.19 S 1003.58 E 272.89 1.30 1040.02 5890.90 13.88 169.38 5731.24 580.54 S 1026.39 E 275.34 2.24 1062.68 5987.39 13.60 168.07 5824.97 594.29 S 1048.87 E 279.82 0.43 1085.55 6083.09 13.29 169.48 5918.05 607.64 S 1070.69 E 284.15 0.47 1107.76 6177.82 13.24 170.15 6010.25 621.01 S 1092.08 E 288.00 0.17 1129.42 6274.47 13.32 167.76 6104.32 634.39 S 1113.87 E 292.25 0.57 1151.57 6374.82 13.31 167.13 6201.97 647.84 S 1136.43 E 297.28 0.14 1174.67 6471.50 13.39 166.14 6296.04 660.57 S 1158.15 E 302.44 0.25 1196.98 6567.58 13.49 166.23 6389.48 673.16 S 1179.83 E 307.77 0.11 1219.31 6663.98 13.50 167.32 6483.22 686.03 S 1201.73 E 312.91 0.26 1241.80 6760.90 13.35 168.67 6577.50 699.29 S 1223.74 E 317.60 0.36 1264.28 6856.86 13.21 169.26 6670.89 712.59 S 1245.37 E 321.82 0.20 1286.28 6950.99 13.49 170.70 6762.48 726.00 S 1266.77 E 325.59 0.46 1307.95 7049.95 13.35 168.74 6858.73 740.09 S 1289.37 E 329.69 0.48 1330.85 7146.98 13.25 166.76 6953.16 753.18 S 1311.18 E 334.42 0.48 1353.16 7243.38 13.23 165.56 7047.00 765.61 S 1332.62 E 339.71 0.29 1375.23 7340.16 13.16 164.09 7141.23 777.63 S 1353.94 E 345.49 0.35 1397.32 7436.85 13.32 166.24 7235.35 789.79 S 1375.34 E 351.15 0.54 1419.46 7533.17 13.27 168.08 7329.08 802.58 S 1396.93 E 356.08 0.44 1441.60 7629.48 12.85 169.03 7422.90 815.58 S 1418.26 E 360.40 0.49 1463.34 7726.47 13.07 170.50 7517.42 828.94 S 1439.67 E 364.26 0.41 1485.04 7822.45 12.95 172.29 7610.94 842.69 S 1461.03 E 367.49 0.44 1506.54 Anna 17A 36 MD (ft) Incl (°) Azim True (°) TVD (ft) VSEC (ft) NS (N/S ft) EW (E/W ft) DLS (°/100ft) Closure (ft) 7918.96 13.04 172.98 7704.98 856.86 S 1482.55 E 370.28 0.19 1528.09 8015.16 12.97 172.45 7798.71 871.02 S 1504.03 E 373.02 0.14 1549.59 8111.78 12.62 168.19 7892.93 884.32 S 1525.11 E 376.61 1.04 1570.92 8208.08 12.65 164.69 7986.90 896.27 S 1545.57 E 381.54 0.80 1591.97 8302.62 12.82 162.38 8079.12 907.21 S 1565.56 E 387.45 0.57 1612.79 8399.25 12.85 163.09 8173.33 918.22 S 1586.05 E 393.82 0.17 1634.22 8495.06 13.53 163.58 8266.61 929.63 S 1607.00 E 400.09 0.72 1656.05 8591.28 14.12 168.85 8360.05 942.61 S 1629.31 E 405.54 1.44 1679.02 8688.21 15.00 178.39 8453.88 958.83 S 1653.45 E 408.18 2.63 1703.09 8782.83 14.89 191.01 8545.32 978.15 S 1677.63 E 406.20 3.44 1726.11 8881.31 15.41 205.05 8640.41 1001.55 S 1701.91 E 398.24 3.75 1747.89 8977.23 17.12 212.20 8732.50 1027.67 S 1725.41 E 385.32 2.74 1767.91 9072.80 19.31 216.11 8823.28 1057.26 S 1750.08 E 368.51 2.62 1788.46 9167.29 21.75 218.90 8911.76 1090.29 S 1776.33 E 348.31 2.78 1810.16 9265.28 23.78 219.38 9002.12 1128.17 S 1805.74 E 324.37 2.08 1834.64 9362.00 23.96 220.96 9090.56 1167.28 S 1835.64 E 299.12 0.69 1859.85 9458.83 25.00 222.37 9178.69 1207.41 S 1865.61 E 272.44 1.23 1885.39 9556.69 26.20 222.91 9266.94 1249.68 S 1896.71 E 243.80 1.25 1912.31 9653.26 28.00 222.04 9352.91 1293.67 S 1929.16 E 214.10 1.91 1941.00 9749.36 29.93 222.85 9436.98 1340.20 S 1963.49 E 182.69 2.05 1971.97 9845.65 31.58 222.77 9519.73 1389.44 S 1999.62 E 149.23 1.71 2005.18 9942.18 33.77 224.50 9600.98 1441.52 S 2037.31 E 113.25 2.47 2040.46 10038.64 36.32 227.56 9679.95 1496.74 S 2075.72 E 73.37 3.21 2077.02 10134.69 37.72 228.81 9756.64 1554.21 S 2114.27 E 30.27 1.65 2114.48 10231.55 38.69 230.92 9832.75 1613.52 S 2152.87 W 15.53 1.68 2152.92 10328.20 40.34 233.24 9907.31 1674.03 S 2190.64 W 64.05 2.29 2191.57 10424.59 42.57 234.96 9979.55 1736.38 S 2228.03 W 115.75 2.60 2231.04 10492.41 43.64 235.29 10029.07 1781.49 S 2254.53 W 153.77 1.61 2259.77 10629.58 45.92 237.36 10126.43 1875.03 S 2308.06 W 234.18 1.97 2319.91 10724.72 46.70 238.45 10192.15 1941.14 S 2344.61 W 292.46 1.17 2362.78 10821.20 48.90 240.13 10256.96 2009.32 S 2381.09 W 353.91 2.62 2407.25 10917.62 51.35 242.09 10318.77 2079.17 S 2416.82 W 418.70 2.98 2452.82 11014.19 53.59 241.92 10377.60 2151.07 S 2452.76 W 486.32 2.32 2500.51 11110.29 55.96 241.82 10433.02 2224.83 S 2489.77 W 555.54 2.47 2551.00 11206.55 58.80 241.54 10484.91 2301.10 S 2528.24 W 626.91 2.96 2604.80 11303.11 61.14 241.94 10533.23 2379.72 S 2567.81 W 700.54 2.45 2661.65 11399.57 63.22 240.75 10578.25 2460.14 S 2608.72 W 775.39 2.42 2721.52 11495.62 64.97 240.83 10620.21 2541.87 S 2650.89 W 850.80 1.82 2784.07 11592.46 66.90 240.65 10659.69 2625.54 S 2694.10 W 927.94 2.00 2849.43 11689.13 68.37 240.80 10696.48 2710.14 S 2737.82 W 1005.92 1.53 2916.76 11785.52 69.41 240.79 10731.19 2795.20 S 2781.69 W 1084.40 1.08 2985.59 11881.77 69.21 240.36 10765.20 2880.48 S 2825.93 W 1162.83 0.47 3055.82 11977.91 69.28 240.46 10799.27 2965.72 S 2870.32 W 1241.01 0.12 3127.11 12074.17 69.26 239.88 10833.34 3051.19 S 2915.10 W 1319.11 0.56 3199.67 12170.53 69.80 241.58 10867.04 3136.62 S 2959.24 W 1397.85 1.75 3272.78 Anna 17A 37 MD (ft) Incl (°) Azim True (°) TVD (ft) VSEC (ft) NS (N/S ft) EW (E/W ft) DLS (°/100ft) Closure (ft) 12267.06 70.67 242.27 10899.68 3221.95 S 3001.99 W 1478.01 1.12 3346.11 12363.51 70.82 242.82 10931.49 3307.14 S 3043.97 W 1558.81 0.56 3419.89 12460.06 71.09 243.11 10963.00 3392.29 S 3085.45 W 1640.10 0.40 3494.27 12557.76 69.99 245.54 10995.55 3477.42 S 3125.37 W 1723.11 2.60 3568.90 12654.76 70.99 246.21 11027.94 3560.94 S 3162.73 W 1806.55 1.22 3642.32 12749.69 71.04 245.92 11058.83 3642.82 S 3199.15 W 1888.60 0.29 3715.02 12849.19 73.41 245.61 11089.20 3729.44 S 3238.04 W 1974.99 2.40 3792.83 12943.91 75.07 245.86 11114.93 3812.80 S 3275.50 W 2058.10 1.77 3868.42 13040.05 75.46 244.57 11139.38 3898.17 S 3314.48 W 2142.51 1.36 3946.66 13136.31 75.86 242.92 11163.22 3984.71 S 3355.74 W 2226.14 1.71 4026.99 13232.67 75.46 243.14 11187.09 4071.77 S 3398.08 W 2309.35 0.47 4108.53 13327.65 75.16 242.87 11211.17 4157.47 S 3439.78 W 2391.21 0.42 4189.27 13418.65 75.39 243.88 11234.30 4239.35 S 3479.22 W 2469.89 1.10 4266.77 13517.05 75.65 244.41 11258.91 4327.51 S 3520.77 W 2555.63 0.58 4350.52 13602.03 75.21 245.09 11280.29 4403.29 S 3555.85 W 2630.01 0.93 4422.79 13670.00 75.21 245.09 11297.64 4463.68 S 3583.53 W 2689.62 0.00 4480.60 An n a 1 7 A 38 4. 2 B i t Re c o r d BI T N O . SI Z E T YP E S/ N JE T S TF A IN O U T FT H R S AV E RO P Ft / H R CONDITION 1 1 2 . 2 5 ” Sm i t h X R C + C Mi l l t o o t h PY 2 9 1 4 3x 1 8 , 1 x 1 4 0. 8 9 6 32 0 0 ’ 5 4 8 6 ’ 19 5 3 ’ 5 5 . 7 5 0 . 4 3 - 3 - W T - A - E - 1 - N O - B H A 2 1 2 . 2 5 ” Sm i t h M D S i 7 1 6 PD C JF 9 9 4 2 9x 1 1 0. 8 3 5 54 8 6 ’ 9 5 2 2 ’ 4 0 3 7 ’ 8 3 . 9 6 5 . 1 1 - 1 - C T - N - X - I - P N - R I G 2R R 1 2 . 2 5 ” Sm i t h M D S i 7 1 6 PD C JF 9 9 4 2 9x 1 1 0. 8 3 5 95 2 2 ’ 1 0 5 6 0 ’ 1 0 3 8 ’ 7 7 . 2 1 6 . 6 2 - 3 - C T - A - X - I n - P N - T D 3 8 . 5 0 ” Sm i t h M D S i 7 1 6 PD C JH 5 9 6 6 4x 1 2 , 4 x 1 1 0. 7 2 0 10 5 6 0 ’ 12 5 3 2 ’ 1 9 7 2 ’ 9 9 . 3 3 3 . 6 4 - 7 - B T - G - X - 7 - C T - P R 4 8 . 5 0 ” Sm i t h M D S i 7 1 6 PD C JH 5 9 6 8 4x 1 2 , 4 x 1 1 0. 7 2 0 12 5 3 2 ’ 13 6 7 0 ’ 1 1 6 5 ’ 8 8 . 5 1 5 . 2 5 - 8 - B T - A - X - 8 - L T - T D An n a 1 7 A 39 4. 3 M u d R e c o r d Co n t r a c t o r : B a r o i d ( H a l l i b u r t o n ) Mu d T y p e : B a r a z a n B a r ( 2 % K C l / G E M G P / B D F - 4 9 9 f l u i d s y s t e m ) Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 11 / 0 2 / 1 3 3 2 0 0 ’ / 3 1 6 3 ’ 9 . 7 3 8 4 1 4 5 / 6 / 7 1 2 . 0 1 / 0 5 . 7 - / 9 4 - - 8 . 0 6 0 0 8 0 11 / 0 3 / 1 3 3 2 0 0 ’ / 3 1 6 3 ’ 9 . 7 3 8 4 1 4 5 / 6 / 7 1 2 . 0 1 / 0 5 . 7 - / 9 4 - - 9 . 4 6 0 0 8 0 11 / 0 4 / 1 3 3 2 0 0 ’ / 3 1 6 3 ’ 9 . 7 3 8 4 1 4 5 / 6 / 7 1 2 . 0 1 / 0 5 . 7 - / 9 4 - - 9 . 4 6 0 0 8 0 11 / 0 5 / 1 3 3 2 0 0 ’ / 3 1 6 3 ’ 9 . 7 3 8 4 1 4 5 / 6 / 7 1 2 . 0 1 / 0 5 . 8 - / 9 4 - - 9 . 4 6 0 0 8 0 11 / 0 6 / 1 3 3 2 0 0 ’ / 3 1 6 3 ’ 9 . 7 3 8 4 1 4 5 / 6 / 7 1 2 . 0 1 / 0 5 . 8 - / 9 4 - - 9 . 4 6 0 0 8 0 11 / 0 7 / 1 3 3 2 0 0 ’ / 3 1 6 3 ’ 9 . 7 3 8 4 1 4 5 / 6 / 7 1 2 . 0 1 / 0 5 . 8 - / 9 4 - - 9 . 4 6 0 0 8 0 11 / 0 8 / 1 3 3 5 3 0 ’ / 3 4 7 5 ’ 9 . 2 4 8 4 1 4 7 / 8 / 0 5 . 1 1 / 0 2 . 9 - / 9 6 - - 9 . 0 1 2 0 0 0 1 2 0 11 / 0 9 / 1 3 3 7 6 0 ’ / 3 6 9 5 ’ 9 . 3 5 2 1 1 1 7 6 / 8 / 9 5 . 6 1 / 0 3 . 9 - / 9 5 1 . 5 - 9 . 0 1 2 0 0 0 1 6 0 11 / 1 0 / 1 3 4 4 8 1 ’ / 4 3 8 4 ’ 9 . 2 5 5 1 1 1 1 8 5 / 7 / 8 5 . 5 1 / 0 4 . 4 - / 9 4 . 5 1 5 9 . 0 1 3 0 0 0 2 0 0 11 / 1 1 / 1 3 4 7 5 9 ’ / 4 6 9 0 ’ 9 . 4 4 7 1 4 1 8 6 / 7 / 8 5 . 5 1 / 0 4 . 4 0 . 5 / 9 4 0 . 5 5 9 . 1 1 3 0 0 0 3 6 0 11 / 1 2 / 1 3 5 4 3 5 ’ / 5 3 7 0 ’ 9 . 3 7 5 0 1 6 1 9 6 / 7 / 8 5 1 / 0 4 . 5 0 . 5 / 9 4 0 . 5 6 9 . 0 1 1 0 0 0 4 8 0 11 / 1 3 / 1 3 5 4 8 6 ’ / 5 4 2 1 ’ 9 . 3 7 5 8 1 4 1 6 7 / 8 / 9 5 1 / 3 4 . 5 0 . 5 / 9 4 0 . 5 5 9 . 3 1 1 0 0 0 2 0 0 11 / 1 4 / 1 3 5 8 6 2 ’ / 5 8 0 0 ’ 9 . 4 4 8 1 5 1 9 6 / 7 / 8 5 1 / 3 5 . 5 0 . 5 / 9 3 0 . 5 5 9 . 0 1 1 0 0 0 2 0 0 11 / 1 5 / 1 3 6 8 1 1 ’ / 6 7 3 0 ’ 9 . 3 4 7 1 6 2 3 6 / 9 / 1 2 5 . 8 1 / 3 5 1 / 9 3 0 . 7 5 6 9 . 1 1 1 0 0 0 2 4 0 11 / 1 6 / 1 3 7 4 2 9 ’ / 7 3 3 0 ’ 9 . 3 5 5 1 1 4 1 8 4 / 7 / 9 5 . 6 1 / 3 5 1 / 9 3 0 . 7 5 6 9 . 0 1 1 5 0 0 1 0 0 11 / 1 7 / 1 3 8 4 6 3 ’ / 8 3 4 3 ’ 9 . 4 5 4 7 1 3 1 8 5 / 7 / 9 6 . 0 1 / 3 5 . 5 1 / 9 2 . 5 0 . 7 5 6 9 . 1 1 1 0 0 0 8 0 11 / 1 8 / 1 3 9 0 3 4 ’ / 8 7 9 2 ’ 9 . 4 5 4 8 1 6 2 0 5 / 7 / 1 0 5 . 4 1 / 3 5 . 5 1 / 9 2 . 5 0 . 7 5 6 9 . 0 1 1 0 0 0 1 0 0 11 / 1 9 / 1 3 9 4 8 1 ’ / 9 4 8 1 ’ 9 . 5 5 6 2 1 2 2 5 / 6 / 8 4 . 0 1 / 2 5 . 8 0 . 5 / 9 3 . 0 0 . 7 5 6 9 . 8 1 1 0 0 0 4 0 11 / 2 0 / 1 3 9 5 2 2 ’ / 9 3 2 7 ’ 9 . 5 7 0 2 2 2 7 5 / 7 / 9 4 . 2 1 / 2 5 . 4 0 . 1 / 9 3 . 5 0 . 5 7 . 5 1 1 . 0 1 1 0 0 0 4 0 11 / 2 1 / 1 3 9 5 2 2 ’ / 9 2 3 7 ’ 9 . 4 6 8 1 9 1 8 5 / 6 / 8 4 . 4 1 / 2 5 . 2 1 / 9 2 . 8 0 . 5 7 . 5 1 0 . 5 1 1 0 0 0 4 0 11 / 2 2 / 1 3 9 5 2 2 ’ / 9 2 3 7 ’ 9 . 5 5 8 1 7 1 3 4 / 5 / 6 4 . 0 1 / 2 5 . 5 0 . 5 / 9 3 0 . 5 7 . 5 1 0 . 6 1 1 0 0 0 4 0 11 / 2 3 / 1 3 9 5 2 2 ’ / 9 2 3 7 ’ 9 . 5 6 0 2 0 1 6 3 / 5 / 6 3 . 7 1 / 2 6 . 3 0 . 5 / 9 2 . 2 0 . 2 5 6 9 . 8 1 1 0 0 0 4 0 11 / 2 4 / 1 3 9 6 2 5 ’ / 9 3 0 0 ’ 9 . 8 5 9 2 0 2 1 5 / 7 / 1 0 4 . 0 1 / 2 7 . 6 0 . 5 / 9 1 0 . 2 5 6 9 . 8 1 1 0 0 0 8 0 11 / 2 5 / 1 3 9 8 3 3 ’ / 9 5 0 8 ’ 1 0 . 0 6 0 2 6 2 5 4 / 6 / 8 3 . 4 1 / 2 8 . 7 0 . 5 / 8 9 . 9 0 . 2 5 6 9 . 5 1 1 0 0 0 4 0 11 / 2 6 / 1 3 1 0 1 2 8 ’ / 9 7 5 2 ’ 1 0 . 1 5 5 8 2 1 2 1 5 / 7 / 9 4 . 0 1 / 2 8 . 3 0 . 5 / 9 0 . 3 0 . 2 5 6 9 . 3 1 1 0 0 0 4 0 11 / 2 7 / 1 3 1 0 3 6 6 ’ / 9 9 2 7 ’ 1 0 . 1 5 7 2 1 2 3 6 / 8 / 1 0 3 . 8 1 / 2 8 . 6 0 . 5 / 9 0 0 . 2 5 6 9 . 3 1 1 0 0 0 4 0 11 / 2 8 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 7 ’ 1 0 . 1 5 7 2 2 2 2 6 / 8 / 1 0 3 . 8 1 / 2 9 . 1 0 . 5 / 8 9 . 5 0 . 2 5 6 9 . 5 1 1 0 0 0 8 0 11 / 2 9 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 7 ’ 1 0 . 1 5 7 2 2 2 1 5 / 8 / 1 0 3 . 8 1 / 2 8 . 3 0 . 5 / 9 0 . 3 0 . 2 5 6 9 . 5 1 1 0 0 0 8 0 11 / 3 0 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 7 ’ 1 0 . 2 5 0 1 6 1 8 7 / 9 / 1 1 4 . 0 1 / 2 8 . 3 0 . 5 / 9 0 . 3 0 . 2 5 6 9 . 5 1 1 0 0 0 4 0 An n a 1 7 A 40 Da t e D e p t h MW (p p g ) VI S (s / q t ) PV Y P Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T p H Cl (ml/l) Ca (ml/l) 12 / 0 1 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 7 ’ 1 0 . 1 5 1 1 5 2 0 5 / 7 / 9 4 . 0 1 / 2 8 . 1 0 . 5 / 9 0 . 5 0 . 2 5 6 9 . 5 1 1 0 0 0 4 0 12 / 0 2 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 7 ’ 1 0 . 1 4 8 1 5 1 5 5 / 7 / 9 4 . 5 1 / 2 8 . 1 0 . 5 / 9 0 . 5 0 . 2 5 6 9 . 6 1 1 0 0 0 8 0 12 / 0 3 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 7 ’ 1 0 . 1 4 4 1 3 1 6 7 / 8 / 9 4 . 8 1 / 2 8 . 1 0 . 5 / 9 0 . 5 0 . 2 5 5 6 . 8 1 1 0 0 0 8 0 12 / 0 4 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 9 . 9 5 1 1 3 1 2 7 / 9 / 1 0 5 . 8 1 / 2 6 . 1 0 . 5 / 9 2 . 5 0 . 2 5 5 8 . 7 1 0 5 0 0 - 12 / 0 5 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 9 . 9 5 0 1 2 1 4 7 / 9 / 1 0 5 . 8 1 / 2 6 . 1 0 . 5 / 9 2 . 5 0 . 2 5 5 8 . 5 1 0 5 0 0 8 0 12 / 0 6 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 9 . 9 5 0 1 2 1 4 7 / 8 / 1 0 5 . 5 1 / 2 6 . 1 0 . 5 / 9 2 . 5 0 . 2 5 5 9 . 0 1 0 5 0 0 1 2 0 12 / 0 7 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 9 . 9 5 5 1 3 1 5 6 / 8 / 9 4 . 6 1 / 2 6 . 1 0 . 5 / 9 2 . 5 - 4 8 . 6 1 0 0 0 0 1 2 0 12 / 0 8 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 1 0 . 1 5 5 1 5 1 7 7 / 1 2 / 1 5 7 . 5 1 / 2 6 . 1 0 . 5 / 9 0 . 0 0 . 2 5 6 6 . 4 1 0 0 0 0 6 4 0 12 / 0 9 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 1 0 . 1 4 8 1 4 1 6 6 / 8 / 1 0 7 . 2 1 / 2 8 . 2 0 . 5 / 9 0 . 5 0 . 1 5 4 . 5 7 . 2 9 0 0 0 2 4 0 12 / 1 0 / 1 3 1 0 5 6 0 ’ / 1 0 0 7 8 ’ 1 0 . 1 5 0 1 4 1 6 6 / 8 / 1 0 7 . 8 1 / 2 8 . 2 0 . 5 / 9 0 . 5 0 . 2 5 4 . 0 6 . 8 9 0 0 0 2 4 0 12 / 1 1 / 1 3 1 0 6 3 7 ’ / 1 0 1 3 1 ’ 1 0 . 6 5 2 2 0 2 3 1 3 / 1 7 / 1 9 3 . 6 1 / 2 1 0 . 6 0 . 5 / 8 8 . 0 0 . 2 5 5 . 0 1 0 . 0 1 1 0 0 0 2 4 0 0 12 / 1 2 / 1 3 1 1 0 7 6 ’ / 1 0 4 1 5 ’ 1 1 . 1 5 5 4 2 5 2 6 9 / 1 6 / 2 0 4 . 6 1 / 2 1 2 . 0 0 . 5 / 8 6 . 7 0 . 2 5 6 . 5 9 . 6 1 0 0 0 0 7 6 0 12 / 1 3 / 1 3 1 1 0 7 6 ’ / 1 0 4 1 5 ’ 1 2 . 2 5 5 4 2 9 2 5 8 / 1 4 / 1 6 5 . 0 1 / 2 1 6 . 0 0 . 5 / 8 2 . 7 0 . 1 5 6 . 0 9 . 8 1 0 5 0 0 7 6 0 12 / 1 4 / 1 3 1 1 1 4 7 ’ / 1 0 4 5 6 ’ 1 2 . 5 5 3 2 7 2 4 8 / 1 4 / 1 6 4 . 8 1 / 2 1 7 . 3 0 . 5 / 8 1 . 4 0 . 2 5 5 . 5 9 . 4 1 0 0 0 0 3 2 0 12 / 1 5 / 1 3 1 1 5 6 1 ’ / 1 0 6 7 3 ’ 1 2 . 6 5 5 7 3 0 3 0 1 1 / 2 0 / 2 3 4 . 8 1 / 2 1 7 . 7 0 . 5 / 8 1 . 0 0 . 2 5 5 . 0 9 . 8 1 0 0 0 0 8 0 12 / 1 6 / 1 3 1 2 0 6 6 ’ / 1 0 8 7 3 ’ 1 2 . 7 0 6 0 3 1 2 6 1 2 / 2 2 / 2 5 5 . 4 1 / 2 1 8 . 3 0 . 5 / 8 0 . 4 0 . 2 5 5 . 5 9 . 4 1 1 0 0 0 8 0 12 / 1 7 / 1 3 1 2 2 9 6 ’ / 1 0 9 3 9 ’ 1 2 . 9 5 4 9 2 3 2 1 7 / 1 1 / 1 5 3 . 8 1 / 2 1 9 . 1 0 . 5 / 7 9 . 6 0 . 2 5 6 . 0 9 . 5 1 1 0 0 0 2 0 12 / 1 8 / 1 3 1 2 4 9 0 ’ / 1 0 9 8 2 ’ 1 2 . 9 5 4 7 2 6 1 4 7 / 1 1 / 1 5 3 . 8 1 / 2 1 9 . 1 0 . 5 / 7 9 . 6 0 . 2 5 6 . 0 9 . 7 1 1 0 0 0 2 0 12 / 1 9 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 4 7 2 5 1 6 7 / 1 3 / 1 8 3 . 5 1 / 2 1 9 . 2 0 . 5 / 7 9 . 5 0 . 2 5 6 . 0 9 . 9 1 1 0 0 0 8 0 12 / 2 0 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 4 7 2 7 1 7 7 / 1 2 / 1 9 3 . 6 1 / 2 1 9 . 3 0 . 5 / 7 9 . 4 0 . 2 5 6 . 0 9 . 8 1 1 0 0 0 2 0 12 / 2 1 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 4 9 3 5 1 5 6 / 1 2 / 1 8 3 . 6 1 / 2 1 9 . 1 0 . 5 / 7 9 . 6 0 . 1 5 6 . 0 1 0 . 0 1 1 0 0 0 2 0 12 / 2 2 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 4 9 2 8 1 9 4 / 1 2 / 1 9 3 . 2 1 / 2 1 8 . 7 0 . 5 / 8 0 . 0 0 . 1 5 6 . 0 9 . 9 1 1 0 0 0 8 0 12 / 2 3 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 5 3 3 4 1 9 8 / 1 2 / 1 8 3 . 0 1 / 2 1 8 . 4 0 . 5 / 8 0 . 0 0 . 2 5 6 . 0 9 . 9 1 5 0 0 0 8 0 12 / 2 4 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 5 6 3 4 1 4 5 / 1 2 / 1 8 3 . 6 1 / 2 1 8 . 5 0 . 5 / 8 0 . 0 0 . 2 5 6 . 0 1 0 . 0 1 4 0 0 0 2 0 12 / 2 5 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 5 8 2 5 2 0 5 / 1 2 / 1 8 3 . 8 1 / 2 1 8 . 5 0 . 5 / 8 0 . 0 0 . 2 0 6 . 0 1 0 . 0 1 4 0 0 0 4 0 12 / 2 6 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 2 . 9 5 4 8 2 7 1 9 6 / 1 2 / 1 8 3 . 8 1 / 2 1 8 . 5 0 . 5 / 8 0 . 0 0 . 2 5 6 . 0 9 . 7 1 4 0 0 0 8 0 12 / 2 7 / 1 3 1 2 5 3 2 ’ / 1 0 9 9 0 ’ 1 3 . 0 0 4 7 2 0 2 2 7 / 9 / 1 2 3 . 8 1 / 2 1 8 . 5 0 . 5 / 8 0 . 0 0 . 2 5 5 . 0 9 . 5 1 4 0 0 0 1 0 0 12 / 2 8 / 1 3 1 2 6 5 2 ’ / 1 1 0 0 4 ’ 1 3 . 0 0 4 4 2 5 1 6 7 / 1 2 / 1 5 3 . 1 1 / 2 1 8 . 9 0 . 5 / 7 9 . 5 0 . 2 5 5 . 0 9 . 4 1 6 0 0 0 8 0 12 / 2 9 / 1 3 1 2 9 1 0 ’ / 1 1 2 1 9 ’ 1 2 . 9 0 4 6 2 5 1 9 8 / 1 6 / 1 9 3 . 3 1 / 2 1 8 . 3 0 . 5 / 8 0 . 0 0 . 2 5 5 . 5 1 0 . 0 1 7 0 0 0 8 0 12 / 3 0 / 1 3 1 3 1 0 4 ’ / 1 1 1 5 6 ’ 1 3 . 4 4 5 1 8 2 3 1 4 / 2 6 / 3 2 3 . 6 2 / 2 2 0 . 5 1 . 0 / 7 7 . 5 0 . 2 5 6 . 3 9 . 3 1 5 0 0 0 1 2 0 12 / 3 1 / 1 3 1 3 2 7 5 ’ / 1 1 1 9 7 ’ 1 3 . 6 5 4 5 1 8 2 5 1 6 / 2 7 / 3 4 4 . 4 2 / 2 2 1 . 3 1 . 5 / 7 6 . 2 0 . 2 5 9 . 0 9 . 1 1 4 0 0 0 1 2 0 01 / 0 1 / 1 4 1 3 4 9 4 ’ / 1 1 2 2 7 ’ 1 3 . 6 5 4 5 1 7 2 1 1 3 / 2 4 / 3 2 3 . 9 2 / 3 2 2 . 1 1 . 0 / 7 5 . 9 0 . 2 5 7 . 5 9 . 7 1 5 0 0 0 1 2 0 Ab b r e v i a t i o n s : MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t Ge l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O/ W = O i l t o W a t e r r a t i o So l s = S o l i d s S d = S a n d c o n t e n t MB T = M e t h y l e n e B l u e A l k , P m = A l k a l i n i t y , M u d pH = A c i d ( < 7 ) / B a s e ( > 7 ) C l = C h l o r i d e s Ca = Ha r d n e s s C a l c i u m n r o r – = N o t R e c o r d e d An n a 1 7 A 41 4. 4 Dr i l l i n g P r o g r e s s C h a r t D A Y S V E R S U S D E P T H 0 10 0 0 20 0 0 30 0 0 40 0 0 50 0 0 60 0 0 70 0 0 80 0 0 90 0 0 10 0 0 0 11 0 0 0 12 0 0 0 13 0 0 0 14 0 0 0 1 0 / 3 1 / 1 3 1 1 / 2 / 1 3 1 1 / 4 / 1 3 1 1 / 6 / 1 3 1 1 / 8 / 1 3 1 1 / 1 0 / 1 3 1 1 / 1 2 / 1 3 1 1 / 1 4 / 1 3 1 1 / 1 6 / 1 3 1 1 / 1 8 / 1 3 1 1 / 2 0 / 1 3 1 1 / 2 2 / 1 3 1 1 / 2 4 / 1 3 1 1 / 2 6 / 1 3 1 1 / 2 8 / 1 3 1 1 / 3 0 / 1 3 1 2 / 2 / 1 3 1 2 / 4 / 1 3 1 2 / 6 / 1 3 1 2 / 8 / 1 3 1 2 / 1 0 / 1 3 1 2 / 1 2 / 1 3 1 2 / 1 4 / 1 3 1 2 / 1 6 / 1 3 1 2 / 1 8 / 1 3 1 2 / 2 0 / 1 3 1 2 / 2 2 / 1 3 1 2 / 2 4 / 1 3 1 2 / 2 6 / 1 3 1 2 / 2 8 / 1 3 1 2 / 3 0 / 1 3 1 / 1 / 1 4 1 / 3 / 1 4 1 / 5 / 1 4 1 / 7 / 1 4 1 / 9 / 1 4 1 / 1 1 / 1 4 1 / 1 3 / 1 4 1/15/14 1/17/14 1/19/14 1/21/14 1/23/14 1/25/14 1/27/14 1/29/14 1/31/14 D E P T H ( F T ) Sl o t R e c o v e r y O p s 12 1 / 4 " H o l e 9 5 / 8 " C a s i n g & R i g S e r v i c e 8- 1 / 2 " H o l e Ru n 7 " L i n e r / S e r v i c e Tu r b i n e s P / U 4 " D r i l l P i p e / Lo g / P e r f / C e m e n t / T e s t Mi l l / R e - D r i l l 6 " H o l e An n a 1 7 A Anna 17A 42 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:9115'MD 9280'MD Country:8863'TVD 9015'TVD Averages Before During After Maximum ROP (fph)40 41 41 77 WOB 11 8 10 21 RPM 120 117 125 136 Mud Weight 10 10 10 10 Chloride Total Gas 194 253 110 430 C1 (ppm)27,507 26,768 9,442 52,454 C2 (ppm)2,849 3,361 1,238 6,997 C3 (ppm)2,357 3,336 1,382 7,564 C4 (ppm)1,126 1,667 907 4,517 C5 (ppm)443 738 444 1,908 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-30%Type Instant Amount Amount trace Distribution spotty Intensity Bright Color Color brown Intensity dull/bright Color Yellow Residual Fluorescence Cut Color Straw Intesity Color Yellow Color Oil Show Rating Free Oil in Mud Comments Report by: 10-30% Yellow Tuffaceous sandstone/sand (9100' - 9290') = dark olive gray to dark gray; salt and pepper appearance; medium grained with scattered coarse to granule and fine grains; well sorted; spheroidal to subdiscoidal and subprismoidal; subangular to angular with subround coarse; loose grains predominant with abundant soft tuff/silt matrix support and occasional to common brittle grain supported fragments; 75% quartz with gray to black lithics and trace reddish brown volcanics, pinkish gray lithics, jasper, and chlorite; non to scattered moderately calcareous; rocks coarsen downward and become unconsolidated and in places consist of conglomeratic sands and occasionally fine gravels; intergrading to thin siltstone in places; interbedded with thin coal and carbonaceous shale stringers in places; the sands correlate to C-5A and C- 5B. Kenai Borough Alaska USA 50-733-20311-01-00Anna 17A Granite Point Cook Inlet Drilling LLC Rig 428 11/19/2013 04:00 - 10:30 hours Pale/Bright James G. Foradas 15-30% bright to moderate yellow sample fluorescence, increasing downward; selected sandstone cuttings in this interval observed in UV light have bright yellow fluorescence, pale to bright yellow cut fluorescence, instantaneous pale to strong milk cut, and residual milk cut; no visible cut or odor were observed, but some stain was observed on cuttings; light oily sheen and foam was observed over shakers; Conversation with the Well Site Geologist for this project indicates that the sands in this interval have been water flooded and may be swept. Slight sheen and foamOil show - see Comments Milk Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:9920'MD 10075'MD Country:9582'TVD 9709'TVD Averages Before During After Maximum ROP (fph)11 24 16 44 WOB 11 9 12 23 RPM 136 132 135 143 Mud Weight 10.0 10.1 10.1+ Chloride 11,000 11,000 11,000 Total Gas 33 103 93 257 C1 (ppm)5,324 10,100 9,587 21,599 C2 (ppm)149 1,172 664 4,225 C3 (ppm)87 1,231 464 3,741 C4 (ppm)45 895 424 2,419 C5 (ppm)11 424 335 1,081 Lithology Cuttings Analysis Odor trace weak Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-40%Type Instant Amount Amount trace Distribution spotty Intensity mod-light Color Color brown Intensity mod-dull Color milky Residual Fluorescence Cut Color yellow-gold white Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: yellow-gold Greg Hammond 10-40% dull to moderate yellow to gold sample fluor; diffuse moderate to weak milky cut; moderate yellow to gold residual cut fluor; no visible cut; no visible residual cut; trace possible stain; trace weak odor. possible sheenpoor Cook Inlet Drilling LLC Rig 428 11/26/2013-11/27/2013 12:10 - 20:50 moderate 50-733-20311-01-00Anna 17A Granite Point Conglomeratic sand/tuffaceous sandstone = olive gray to dark gray; salt and pepper appearance; scattered brownish to yellowish gray tuff; upper fine to upper medium predominant with abundant coarse to 5mm pebble fragments; grades to very fine; moderately to locally well sorted with unsorted very fine volcanics weathered from tuff matrix; subangular to angular with very angular shards and scattered subround granule; subdiscoidal to spheroidal predominant with common discoidal and prismoidal; loose grains predominant with common to rare tuff/silt matrix and trace grain support; 70% quartz with gray to black lithics/mafics, opaque reddish brown volcanics and jasper, greenish gray lithics, clastic coal, and reworked ash/tuff fragments; very to moderately calcareous. Correlates to C-8 sands. Kenai Borough Alaska USA none Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:5:14 AM End Time:1:22 PM County:Depth Start End State:10150'MD 10220'MD Country:20131127'TVD 20131127'TVD Averages Before During After Maximum ROP (fph)8 13 16 20 WOB 13 11 11 15 RPM 143 139 145 159 Mud Weight 10.10 10.10 10.10 10.10 Chloride 11,000 11,000 11,000 11,000 Total Gas 45 37 37 65 C1 (ppm)6,516 5,961 6,868 9,598 C2 (ppm)100 130 106 220 C3 (ppm)65 93 34 175 C4 (ppm)119 38 13 117 C5 (ppm)65 11 9 47 Lithology Cuttings Analysis Odor trace Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-40%Type Instant Amount Amount trace Distribution patchy Intensity mod-pale Color Color brown Intensity dull/bright Color milk Residual Fluorescence Cut Color Gold yellow Intesity Color Yellow/gold Color Oil Show Rating Free Oil in Mud Comments Report by: Gold James G. Foradas Dull gold fluorescence; pale-strong milk cut; weak straw to clear visible cut; milky yellow white cut fluorescence; 10-40% sample fluorescence; show improves downward.Conversation with the Well Site Geologist for this project indicates that the sands in this interval have been water flooded and may be swept. Slight sheen and foamOil show - see Comments Cook Inlet Drilling LLC Rig 428 11/27/2013 Dull-bright Tuffaceous sandstone (10150' - 10220') = olive gray to pale brown with light and dark salt and pepper hues; lower very fine to lower medium grained with some coarser; fair to well sorted; subrounded to rounded; low to high sphericity; some polish and frosting; unconsolidated to easily friable; matrix supported with ash/tuff matrix; slightly calcareous; composed mostly of quartz (60%) and light and dark volcanics; intergrading with tuffaceous siltstone; interbedded with thin carbonaceous shale. This interval correlates with the lower Tyonek 9A sand predicted for this well. 10-30% Yellow 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:7:20 PM End Time:8:45 PM County:Depth Start End State:11469 MD 11529 MD Country:10608 TVD 10634 TVD Averages Before During After Maximum ROP (fph)38 49 48 73 WOB 16 15 13 18 RPM 136 142 143 157 Mud Weight 12.60 12.60 12.60 12.60 Chloride 11,000 11,000 11,000 11,000 Total Gas 36 73 65 173 C1 (ppm)6,296 10,630 12,682 24,104 C2 (ppm)245 661 397 1,657 C3 (ppm)203 771 194 2,289 C4 (ppm)140 567 135 1,668 C5 (ppm)53 199 28 648 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 90%Type Instant Amount Amount none Distribution even Intensity pale Color Color Intensity bright Color bluish Residual Fluorescence Cut Color white-gold white Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: Gold joshua dubowski bright whitish gold fluorescence on 90% of sample. Instantaneous pale bluish white cut. Weak gold residual cut. Best sample was from 11490' Slight sheen and foam Cook Inlet Drilling LLC Rig 428 12/15/2013 pale sand/tuffaceous sandstone = pale yellowish gray to pale grayish white; unconsolidated to soft; lower medium to upper fine to lower fine to upper medium; poor sorting; sub angular to angular to occasional sub rounded; sub spherical to sub discoidal; poor sorting; impact abraded quartz; minor amount of 2- 4mm quartz grains present; tuffaceous sandstone is grain supported; tuff/ash matrix; slightly calcareous; carbonaceous shale siltstone and tuffaceous claystone all common but not abundant; 90% whitish gold; pale gold instantaneous cut; no odor. 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # 5 Operator: Hilcorp Alaska LLC Well: API Number: Field: Date: Rig: Start Time: 11:23 AM End Time: 1:14 PM County: Depth Start End State: 11910'MD 11960'MD Country: 10,819'TVD 10,837'TVD Averages Before During After Maximum ROP (fph) 28 35 25 43 WOB 15 11 13 15 RPM 137 141 142 152 Mud Weight 12.65 12.65 12.65 12.65 Chloride 10,000 10,000 10,000 10,000 Total Gas 19 19 20 84 C1 (ppm) 3,773 3,229 2,434 12,389 C2 (ppm) 250 255 731 938 C3 (ppm) 53 104 195 394 C4 (ppm) 11 16 88 51 C5 (ppm) - - - - Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace - 10% Type Instant Amount Amount trace Distribution spotty/mottled Intensity dull/weak Color Color brown Intensity dull/bright Color pale bl/yel Residual Fluorescence Cut Color yellow/orange Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: yellow/orange D. Muller Slight black sheen and foam Pale/Bright Tuffaceous sandstone = reddish grey to dark reddish grey, light light grey to pinkish grey, greyish brown to darkish brown; dominantly lower fine to upper medium grains, occasional lower very fine and some lower and upper coarse, trace to 10% conglomerate; moderate sorted to well sorted at lower depth; dominant sub- angular to subrounded, secondary angular and some well rounded; moderate sphericity to moderate discoidal; very friable to soft and some slightly firm (only darker colored cuttings), abundant loose grains; grain supported with tuff matrix, increasing tuff matrix with depth; before 11950' abundant carbonaceous inclusions with trace mica, green stone, and carbonaceous siltstone; after 11950, very few inclusions -- dominant quartz with only tuff matrix. 10-3-% yellow/orange 50-733-20311-01-00 Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/16/2013 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report #6 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:3:20 PM End Time:4:20 PM County:Depth Start End State:11997'MD 12022'MD Country:10,850'TVD 10,859'TVD Averages Before During After Maximum ROP (fph)24 32 14 14 WOB 14 16 21 21 RPM 143 144 145 155 Mud Weight 12.70 12.70 12.70 12.70 Chloride 11,000 11,000 11,000 11,000 Total Gas 24 49 10 76 C1 (ppm)3,333 10,542 793 18,448 C2 (ppm)1,455 3,245 149 5,218 C3 (ppm)346 1,458 101 2,593 C4 (ppm)227 977 61 1,632 C5 (ppm)2 208 23 466 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount NONE Type NONE Amount Amount Distribution NONE Intensity NONE Color Color Intensity NONE Color NONE Residual Fluorescence Cut Color NONE Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/16/2013 NONE NONE NONE Josh Dubowski trace to no fluorescence but large ratio of heavy gasses. NONE conglomeratic sand/tuffaceous sandsotne = dark medium gray to medium gray with brownish hues; moderate array of grain sizes with upper fine to upper medium being the most abundant; 2-8mm quartz and volcanic grains common; occasionally impact abraded; poor sorting overall with some well sorted sandstone clasts; grains are sub spherical to sub discoidal; sub angular to sub rounded to angular; sandstones are typically grain supported; tuff/ash matrix; slightly calcareous; occasional siltstone with embedded carbonaceous shale. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # 7 Operator: Hilcorp Alaska LLC Well: API Number: Field: Date: Rig: Start Time: 4:27 PM End Time: 10:47 PM County: Depth Start End State: 12025'MD 12066'MD Country: 10,860'TVD 10,873'TVD Averages Before During After Maximum ROP (fph) 35 27 18 24 WOB 15 17 19 21 RPM 145 135 135 151 Mud Weight 12.70 12.70 12.70 12.70 Chloride 11,000 11,000 11,000 11,000 Total Gas 11 37 12 92 C1 (ppm) 928 5,386 1,844 14,437 C2 (ppm) 171 716 234 1,719 C3 (ppm) 116 494 171 1,166 C4 (ppm) 69 288 101 679 C5 (ppm) 28 152 53 369 Lithology Cuttings Analysis Odor trace Fluorescence Cut Fluorescence Residual Cut Stain Amount 30% Type v. slow Amount Amount trace Distribution scat Intensity weak Color Color pale brown Intensity bright Color white Residual Fluorescence Cut Color white Intesity Color none gold Color Oil Show Rating Free Oil in Mud Comments Report by: 50-733-20311-01-00 Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/16/2013 NONE NONE gold Josh Dubowski mod conglomeratic sand/tuffaceous sandsotne = dark medium gray to medium gray with brownish hues; moderate array of grain sizes with upper fine to upper medium being the most abundant; 2-8mm quartz and volcanic grains common; occasionally impact abraded; poor sorting overall with some well sorted sandstone clasts; grains are sub spherical to sub discoidal; sub angular to sub rounded to angular; sandstones are typically grain supported; tuff/ash matrix; slightly calcareous; occasional siltstone with embedded carbonaceous shale. bright goldish white fluorescence on 30% of sample; extremely slow pale white cut; trace oil stains on grains; no odor. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 8 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:2:53 PM End Time:4:50 PM County:Depth Start End State:12069'MD 12136'MD Country:10,854'TVD 10,895'TVD Averages Before During After Maximum ROP (fph)24 22 12 29 WOB 19 20 24 21 RPM 133 143 136 153 Mud Weight 12.80 12.80 12.80 12.80 Chloride 11,000 11,000 11,000 11,000 Total Gas 38 23 9 59 C1 (ppm)5,758 3,533 1,108 7,334 C2 (ppm)704 539 195 1,231 C3 (ppm)497 395 113 971 C4 (ppm)291 209 47 619 C5 (ppm)156 106 - 308 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace - 15%Type very slow Amount Amount trace Distribution spotty-entire Intensity dull/weak Color Color brown Intensity dull-mild tr. Bright Color pale bl/yel Residual Fluorescence Cut Color yellow/orange Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/17/2013 50-80% yellow/orange yellow/orange D. Muller the disappearance of C4 was used to pick the end of the show interval and corresponded to diminishing fluoresence. Samples afterward exhibited significantly weaker fluoresence with almost no cut till MD 12,170' - 12,177'. this 7' interval had stronger show components than this current show # 8, but was too short for a seperate report. The interval 12170' - 12177' contained more greenstone, and green stained sandstone, and was during a drilling break that also produced higher gas peaking at 29 units; 18 higher than background of 11u. Slight black sheen and foamOil show - see Comments Pale/Bright Conglomeratic sand/tuffaceous sandstone = dark medium gray to medium gray with brownish hues; moderate array of grain sizes with upper fine to upper medium being the most abundant; 2-8mm quartz and volcanic grains common; occasionally impact abraded; poor sorting overall with some well sorted sandstone clasts; grains are sub spherical to sub discoidal; sub angular to sub rounded to angular; sandstones are typically grain supported; tuff/ash matrix; slightly calcareous; occasional siltstone with embedded carbonaceous shale; bright goldish white fluorescence on 30% of sample; extremely slow pale white cut; trace oil stains on grains; no odor. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #9 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:12:30 PM End Time:2:30 AM County:Depth Start End State:12206'MD 12328'MD Country:10,879'TVD 10,947'TVD Averages Before During After Maximum ROP (fph)7 15 8 13 WOB 26 20 19 27 RPM 145 137 82 155 Mud Weight 12.95 12.95 12.95 12.95 Chloride 11,000 11,000 11,000 11,000 Total Gas 8 9 7 24 C1 (ppm)905 1,691 1,511 4,431 C2 (ppm)156 303 268 922 C3 (ppm)118 203 153 698 C4 (ppm)53 138 119 467 C5 (ppm)- 56 79 337 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-40%Type xt-vry slw Amount Amount trace Distribution spotty Intensity mod-dull Color Color brown Intensity mild - brt Color pale blue Residual Fluorescence Cut Color wht-gld to white Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: gren-yel Josh Dubowski moderate to poor show overall. Best sample cut was at 12310 and 12320. Both had a visible, slow cut with a bright yellow residual ring. noneOil show - see Comments Pale/Bright Conglomeratic sand = light medium gray to medium gray with pale brown hues; lower medium to upper fine to lower coarse to upper very fine; poor sorting; angular to sub angular to occasionally sub rounded; discoidal to sub spherical; unconsolidated to trace firmly friable clasts; grain supported; 2-10mm sized grains common; impact abbreded grains common; fluorescence ranges from 10-40%; very slow pale white cut; moderate gold residual ring; trace odor. none none 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/17/2013 - 12/18/2013 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #10 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:12:02 AM End Time:11:29 PM County:Depth Start End State:12321'MD 12518'MD Country:10,917'TVD 10,988'TVD Averages Before During After Maximum ROP (fph)15 11 3 15 WOB 23 22 26 29 RPM 139 132 116 149 Mud Weight 12.95 12.95 12.95 12.95 Chloride 11,000 11,000 11,000 11,000 Total Gas 6 7 1 25 C1 (ppm)1,118 1,606 710 6,410 C2 (ppm)220 290 84 1,289 C3 (ppm)150 205 - 1,036 C4 (ppm)106 117 20 656 C5 (ppm)74 89 - 380 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount 5 - 10%Type slow Amount Amount trace Distribution spotty-full Intensity dull/weak Color Color brown Intensity dull-mild bright Color pale bl/yel Residual Fluorescence Cut Color orange/yellow Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/18/2013 - 12/19/2013 10-30% yellow/orange yellow/orange D. Muller / J. Dubowski Slightly intenser show qualities from 12380' - 12430'. Slight black sheen and foamOil show - see Comments Pale/Bright Tuffaceous sandstone: light grey with slight light red; upper very fine to lower medium, rare coarse grains; moderate sorting; sub rounded to sub angular; highly spherical to sub discoidal; larger grains exhibit frosting/impact abrasion; dominant hard to firm, occasional very friable and rare very hard; grain supported with dominant tuff/ash and some silt matrix; include some pyrite, green-stone, trace shale at 12450'+; some clasts stained green; 12320'-12450' have 5 - 10% dull to mildly bright yellow mineral fluorescence with very slow weak cloudy milky yellow/blue cut and dull yellow/orange residual ring cut, slight dark brown oil stain and no odor, mild oily sheen on shakers. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #11 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:5:19 PM End Time:6:02 PM County:Depth Start End State:13065'MD 13078'MD Country:11,148'TVD 11,151'TVD Averages Before During After Maximum ROP (fph)13 19 14 34 WOB 17 20 16 21 RPM 135 130 125 143 Mud Weight 12.90 12.90 12.90 12.90 Chloride 17,000 17,000 17,000 17,000 Total Gas 13 15 13 23 C1 (ppm)1,041 1,418 935 2,139 C2 (ppm)179 284 162 412 C3 (ppm)105 130 59 222 C4 (ppm)- 52 - 147 C5 (ppm)- - Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount 15%Type x-slow Amount Amount none Distribution spotty Intensity dull/weak Color Color Intensity dull-mild Color blue/white Residual Fluorescence Cut Color orange/yellow Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/18/2013 - 12/19/2013 orange/gold J. Dubowski noneweak V pale Tuffaceous sandstone/conglomeratic sand = medium gray to dark medium gray with pale brown hues; unconsolidated to soft to trace hard; poor sorting; lower coarse to upper fine to upper very fine grained; sub rounded to sub angular; sub spherical to sub discoidal; 2-8mm grains common; grain supported by tuff/ash matrix; moderatly calcareous; variety of secondary minerals including green stone, feldpar, carbonaceous shale and various other dark lithics; dark brown siltstone common; good to moderate induration; blocky fracture; 15% moderate to dull gold sample fluorescence; x-slow pale bluish white cut; very weak orangish gold residual ring; no odor. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #12 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:7:00 AM End Time:2:58 PM County:Depth Start End State:13137'MD 13201'MD Country:11,164'TVD 11,180'TVD Averages Before During After Maximum ROP (fph)10 14 6 12 WOB 22 24 22 53 RPM 143 128 119 148 Mud Weight 13.60 13.60 13.60 13.60 Chloride 15,000 15,000 15,000 15,000 Total Gas 10 31 15 103 C1 (ppm)1,148 3,258 3,682 11,602 C2 (ppm)179 561 609 2,020 C3 (ppm)93 394 372 1,323 C4 (ppm)13 205 168 747 C5 (ppm)- 83 - 401 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount Trace - 20%Type very slow Amount Amount NONE Distribution mottled-full Intensity dull/weak Color Color NONE Intensity dull Color pale yellow Residual Fluorescence Cut NONE Color yellow/orange Intesity Color NONE Color Oil Show Rating Free Oil in Mud Comments Report by: yellow/orange D. Muller 13155' contained first mineral fluorescence: <1% very bright white/blue over almost 100% of individual cuttings. No cut. No residual cut. 100% remaining mineral fluorescence after attempted cut. 13170’ contained 20 – 25% mineral fluorescence: dull yellow over most to all of the sample (entire to mottled). Slow weak cloudy yellow/blue cut. Moderate residual ring cut moderately bright yellow/gold. 0- 10% remaining mineral fluorescence. Slight black sheen and foamOil show - see Comments Pale/Bright Carbonaceous shale: dark reddish brown to reddish black to black; soft to moderately firm; brittle to crumbly; poorly indurated; irregular grading to blocky and slightly Conchoidal fracture; massive grading to sightly platy/blocky cutting habit; earthy grading to vitreous luster; silty grading to smooth texture; massive structure, sometimes interlaced thin bedding of carbonaceous shale with coal. Some coal, tuffaceous sandstone and carbonaceous siltstone. 0-100% yellow/orange 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/31/2013 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #13 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:4:45 PM End Time:9:44 PM County:Depth Start End State:13214'MD 13254'MD Country:11,182'TVD 11,192'TVD Averages Before During After Maximum ROP (fph)6 8 8 10 WOB 22 20 22 22 RPM 121 135 132 139 Mud Weight 13.60 13.60 13.60 13.60 Chloride 15,000 15,000 15,000 15,000 Total Gas 16 22 16 32 C1 (ppm)3,145 1,849 1,472 2,658 C2 (ppm)532 395 319 580 C3 (ppm)324 258 157 452 C4 (ppm)150 155 81 296 C5 (ppm)1 57 5 163 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount >20%Type xslow Amount Amount trace <5%Distribution scattered Intensity dull/weak Color Color pale yel/brn Intensity mod-brt Color gld-wht Residual Fluorescence Cut none Color wht-gld Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/31/2013 none/clear none/clear yellow/orange J. Dubowski Weak overall fluorescence. 10-20% pale to moderate whitish gold. Extremely slow milky golish white to no cut fluorescence. Trace to Pale residual dull yellowish orange residual fluorescence. noneOil show - see Comments Pale tuffaceous sandstone/conglomeratic sand = medium gray to dark medium gray with pale brown and green hues; unconsolidated to soft to trace firm clasts; lower mediumto upper fine to lower coarse; sub angular to angular; sub discoidal to sub spherical; poor to moderate sorting; tuff ash matrix; grain supported; partially calcareous; quartz dominated with carbonaceous shale, green stone and other dark lithics common; well indurated blackish gray siltstone semi common. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report # 14 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:22:38:36 End Time:6:22:29 County:Depth Start End State:13260'MD 13325'MD Country:11,194'TVD 11,207'TVD Averages Before During After Maximum ROP (fph)7 12 8 17 WOB 21 21 22 24 RPM 135 130 137 142 Mud Weight 13.60 13.60 13.60 13.60 Chloride 15,000 15,000 15,000 15,000 Total Gas 21 20 17 47 C1 (ppm)1,937 1,705 1,736 3,548 C2 (ppm)422 369 349 783 C3 (ppm)261 257 206 623 C4 (ppm)156 143 87 344 C5 (ppm)55 91 0 268 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount 20%Type mod Amount Amount trace <10%Distribution scattered Intensity dull/weak Color Color pale yel/brn Intensity mod-brt Color pale yellow Residual Fluorescence Cut none-v faint Color wht-gld Intesity Color vpale straw Color Oil Show Rating Free Oil in Mud Comments Report by: yellow/orange J. Dubowski / D. Muller 13300 Contained 25% sample fluorescence and had the highest quality cut with several moderate light milky yellow streamers. Bright whitish gold residual fluorescence and pale straw residual cut. noneOil show - see Comments Pale Tuffaceous sandstone/conglomeratic sand = medium gray to dark medium gray with pale brown and green hues; unconsolidated to soft to trace firm clasts; lower medium to upper fine to lower coarse; sub angular to angular; sub discoidal to sub spherical; poor to moderate sorting; tuff ash matrix; grain supported; partially calcareous; quartz dominated with carbonaceous shale, green stone and other dark lithics common; well indurated blackish gray siltstone semi common; 25% sample fluorescence; moderate streaming cut fluorescence; pale straw residual cut and milky yellow residual fluorescence. weak pale-straw 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 12/31/2013 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #15 Operator:Hilcorp Alaska LLC Well:API Number: Field:Date: Rig:Start Time:14:53:00 End Time:9:13:00 County:Depth Start End State:13406'MD 13640'MD Country:11,231'TVD 11,276'TVD Averages Before During After Maximum ROP (fph)14 18 14 22 WOB 25 25 25 30 RPM 123 132 137 143 Mud Weight 13.65 13.65 13.65 13.65 Chloride 15,000 15,000 15,000 15,000 Total Gas 22 21 17 48 C1 (ppm)2,382 2,277 1,556 4,874 C2 (ppm)388 438 328 1,014 C3 (ppm)314 357 198 884 C4 (ppm)204 220 134 542 C5 (ppm)- 125 128 359 Lithology Cuttings Analysis Odor NONE Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-50%Type xslow-mod Amount Amount trace <5%Distribution scattered Intensity dull/weak Color Color pale yel/brn Intensity mod-brt Color pale yel/whtResidual Fluorescence Cut none/clear Color wht-gld Intesity Color none/clear Color Oil Show Rating Free Oil in Mud Comments Report by: yellow/orange J. Dubowski / D. Muller Overall weak shows. 13490' and 13560' only samples with a weak pale brown to pale amber residual cut. Sample and cut fluorescences increasing down through the interval. No free oil or odor observed. Oil fluorescence visible in tuff/ash matrix and in fractures of conglomerate quartz sands. noneOil show - see Comments Pale Conglomeratic sand(13400' - 13580') = medium gray to dark gray with pale brown and green hues; unconsolidated to trace moderatly hard clasts; angular to sub angular; upper coarse to upper fine; poor sorting; sub discoidal to sub spherical; 2-8mm clasts common; impact abraded clast seen throughout; quartz dominated; grrenstone, carbonaceous shale, siltstone and other dark lithics are common; grain supported; minor amount of ash/tuff material. Conglomeratic sand (13580' - 13700') = light greenish grey to dark greenish grey; upper very fine to upper coarse grains; poor sorting; well rounded to sub angular; dominant highly spherical, secondary highly discoidal; unconsolidated, tuffaceous sandstones very friable; individual grains mostly translucent and opaque white, occasional light red and pale to dark green; quartz mineral weak/trace pale-straw 50-733-20311-01-00Anna 17A Granite Point Kenai Borough Alaska USA Cook Inlet Drilling LLC Rig 428 1/1/2014 Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Anna 17A 43 6 DAILY DRILLING REPORTS Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 9, 2013 DEPTH 3756' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 3534' 24 HOUR FOOTAGE 222' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3675' 16.84 3613.12' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12-1/4" Smith XR+C Milltooth PY2914 3x18, 1x14 3534' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 93.6 @ 3653 2.9 @ 3552 30.0 47.50 FT/HR SURFACE TORQUE 46818 @ 3724 18 @ 3599 5080.0 9622.12 AMPS WEIGHT ON BIT 41 @ 3724 0 @ 3633 13.1 18.46 KLBS ROTARY RPM 249 @ 3724 0 @ 3554 16.7 46.79 RPM PUMP PRESSURE 1411 @ 3664 884 @ 3554 1033.0 1128.57 PSI DRILLING MUD REPORT DEPTH 3760' MW 9.3 VIS 52 PV 11 YP 17 FL 4.9 Gels 6/8/9 CL- 12000 FC 1/0 SOL 3.9 SD 1.5 OIL 0/95 MBT - pH 9.0 Ca+ 160 Alk 0.55 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 453 @ 3648 26 @ 3753 152.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 93181 @ 3648 5599 @ 3753 28658.2 CONNECTION GAS HIGH ETHANE (C-2) 156 @ 3743 0 @ 3551 40.8 AVG PROPANE (C-3) 26 @ 3581 0 @ 3717 7.6 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 70u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone/claystone; sand/sandstone; coals PRESENT LITHOLOGY Siltstone/claystone DAILY ACTIVITY SUMMARY Clean solids from pits; organize deck; seal under shakers; change out discharge and suction mud pumps; modify damaged screens; transfer fluid to pits. Open BOP; break circulation at 3500’; pump at 16 bbl/min to shear mud and receive survey. Time drill/slide from 3534’ to 3571’. Rotary drill and slide as per DD from 3571’ to 3756’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $2,910, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 10, 2013 DEPTH 4481' PRESENT OPERATION Rig maintenance TIME 24:00 YESTERDAY 3756' 24 HOUR FOOTAGE 725' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4349.55' 16.98 176.74 4257.95' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12-1/4" Smith XR+C Milltooth PY2914 3x18, 1x14 3534' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 657.8 @ 4043 1.2 @ 4046 59.8 75.28 FT/HR SURFACE TORQUE 14421 @ 4120 14 @ 4456 9384.2 12367.38 AMPS WEIGHT ON BIT 118 @ 4045 0 @ 4107 26.4 34.51 KLBS ROTARY RPM 72 @ 4246 0 @ 4428 47.5 57.69 RPM PUMP PRESSURE 1604 @ 4456 1016 @ 3951 1356.4 1397.13 PSI DRILLING MUD REPORT DEPTH 4481' MW 9.25 VIS 51 PV 11 YP 18 FL 5.5 Gels 5/7/8 CL- 13000 FC 1/0 SOL 4.4 SD 1 OIL 0/94.5 MBT 5 pH 9.0 Ca+ 200 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 694 @ 4151 12 @ 3793 211.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 136945 @ 4151 2115 @ 3793 40270.8 CONNECTION GAS HIGH ETHANE (C-2) 760 @ 4010 5 @ 3793 147.6 AVG PROPANE (C-3) 481 @ 4231 0 @ 3791 79.8 CURRENT BUTANE (C-4) 650 @ 4010 1 @ 4339 40.1 CURRENT BACKGROUND/AVG PENTANE (C-5) 53 @ 4001 0 @ 4137 4.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Siltstone/claystone, sands/sandstones, coals PRESENT LITHOLOGY Siltstone/claystone, sand/tuffaceous sandstone/conglomeratic sand DAILY ACTIVITY SUMMARY Drill from 3756’ to 4481’ with sweeps at 4046’ and 4232’. Work pipe while circulating bottoms up with one pump. Trip out from 4481’ to 3564’. Work on sand trap and change swab on pump one; rig maintenance. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $2,910, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 11, 2013 DEPTH 4752' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 4481' 24 HOUR FOOTAGE 271' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4735.25' 18.35 185.25 4624.58' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12-1/4" Smith XR+C Milltooth PY2914 3x18, 1x14 3534' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 165.3 @ 4633 3.3 @ 4741 54.1 22.56 FT/HR SURFACE TORQUE 13903 @ 4516 21 @ 4620 11596.4 11161.37 AMPS WEIGHT ON BIT 60 @ 4621 0 @ 4523 30.8 30.51 KLBS ROTARY RPM 74 @ 4740 0 @ 4620 61.1 67.62 RPM PUMP PRESSURE 1712 @ 4563 1085 @ 4482 1484.5 1514.78 PSI DRILLING MUD REPORT DEPTH 4759' MW 9.4 VIS 47 PV 14 YP 18 FL 5.5 Gels 6/7/8 CL- 13000 FC 1/0 SOL 4.4 SD 0.5 OIL 0.5/94.0 MBT 5 pH 9.1 Ca+ 360 Alk 0.5 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 631 @ 4648 27 @ 4711 129.1 TRIP GAS 522u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 138600 @ 4648 4905 @ 4711 24250.8 CONNECTION GAS HIGH ETHANE (C-2) 286 @ 4648 8 @ 4711 44.0 AVG PROPANE (C-3) 51 @ 4648 0 @ 4566 10.5 CURRENT BUTANE (C-4) 8 @ 4727 0 @ 4703 0.2 CURRENT BACKGROUND/AVG 70u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone/sand, tuffaceous siltstone/claystone, coals PRESENT LITHOLOGY Tuffaceous siltstone/claystone DAILY ACTIVITY SUMMARY Finish rig maintenance; monitor the well. Pressure test both pumps to 2500 psi; test down hole tools and pumps at the shoe. Trip in from 3564’; ream/wash from 4527’. Gas alarm in pits; muster; worked pipe and pumped bottoms up. Drill from 4481’ to 4752’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,410, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Nov 12, 2013 DEPTH 5420' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 4752' 24 HOUR FOOTAGE 668' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5409.10' 16.86 181.51 5265.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12-1/4" Smith XR+C Milltooth PY2914 3x18, 1x14 3534' 5486' 1953' 55.7 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 158.7 @ 4909 1.1 @ 4986 48.0 27.71 FT/HR SURFACE TORQUE 19366 @ 5093 10 @ 4814 11422.0 12754.00 AMPS WEIGHT ON BIT 69 @ 4909 0 @ 5196 30.8 37.80 KLBS ROTARY RPM 104 @ 5362 0 @ 4814 59.1 90.72 RPM PUMP PRESSURE 1754 @ 5325 519 @ 5387 1532.8 1601.10 PSI DRILLING MUD REPORT DEPTH 5435' MW 9.37 VIS 50 PV 16 YP 19 FL 5.0 Gels 6/7/8 CL- 11000 FC 1/0 SOL 4.5 SD 0.5 OIL 0.5/94.0 MBT 6 pH 9.0 Ca+ 480 Alk 0.45 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 540 @ 5042 15 @ 5343 93.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 106753 @ 5042 3143 @ 5090 18274.7 CONNECTION GAS HIGH ETHANE (C-2) 3156 @ 5023 4 @ 5355 121.0 AVG PROPANE (C-3) 1115 @ 5023 0 @ 5347 47.1 CURRENT BUTANE (C-4) 8 @ 4889 0 @ 4904 0.1 CURRENT BACKGROUND/AVG 35u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone/sand/conglomeratic sand, tuffaceous siltstone/claystone, coals PRESENT LITHOLOGY Tuffaceous siltstone/claystone, tuffaceous sandstone/sand DAILY ACTIVITY SUMMARY Rotary drilling from 4752’ to 5311’. Slide from 5311’ to 5342’. Rotary drilling from 5342’ to 5420’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 13, 2013 DEPTH 5486' PRESENT OPERATION Rig service TIME 24:00 YESTERDAY 5420' 24 HOUR FOOTAGE 66' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5409.10' 16.86 181.51 5265.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12-1/4" Smith XR+C Milltooth PY2914 3x18, 1x14 3534' 5486' 1953' 55.7 3-3-WT-A-E-I-NO BHA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 45.4 @ 5452 7.7 @ 5477 27.9 27.47 FT/HR SURFACE TORQUE 46960 @ 5463 20 @ 5469 12738.7 12050.01 AMPS WEIGHT ON BIT 44 @ 5485 10 @ 5454 33.5 44.02 KLBS ROTARY RPM 369 @ 5461 0 @ 5463 93.8 76.14 RPM PUMP PRESSURE 1700 @ 5467 1478 @ 5476 1611.1 1535.88 PSI DRILLING MUD REPORT DEPTH 5486' MW 9.37 VIS 58 PV 14 YP 16 FL 5.0 Gels 7/8/9 CL- 11000 FC 1/3 SOL 4.5 SD 0.5 OIL 0.5/94 MBT 5 pH 9.3 Ca+ 200 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 339 @ 5450 48 @ 5425 99.4 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 84650 @ 5450 10443 @ 5425 21985.9 CONNECTION GAS HIGH ETHANE (C-2) 247 @ 5450 20 @ 5425 56.7 AVG PROPANE (C-3) 60 @ 5450 7 @ 5425 17.0 CURRENT BUTANE (C-4) 8 @ 5450 0 @ 5439 0.6 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 5486 0 @ 5486 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous siltstone, tuffaceous sandstone/sand, coal PRESENT LITHOLOGY Tuffaceous siltstone, tuffaceous sandstone/sand DAILY ACTIVITY SUMMARY Drill from 5420’ to 5486’. Pump sweep; work pipe. Attempt to trip out of hole; swabbing; wash out of hole from 5486’ to 3444’; no tight hole. Electrical check and tape up electrical service loop on top drive. Pump dry job; blow down top drive and mud line; trip out of hole to 686’. Turbine generator down; start generators and pumps. Trip out of hole and lay down BHA #1. Service top drive, blocks, crown, drawworks; lay down service loop; calibrate trip tank; rig housekeeping. Move one top drive service loop over and pick up a new service loop. Monitor well on trip tank; static. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 14, 2013 DEPTH 5863' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 5486' 24 HOUR FOOTAGE 377' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5890.90' 13.88 169.38 5731.24' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 TFA=0.835 5486' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 138.1 @ 5742 3.0 @ 5819 67.9 66.58 FT/HR SURFACE TORQUE 19222 @ 5656 21 @ 5570 16456.0 15963.78 AMPS WEIGHT ON BIT 44 @ 5486 2 @ 5865 9.8 6.95 KLBS ROTARY RPM 144 @ 5766 0 @ 5570 120.5 111.26 RPM PUMP PRESSURE 1670 @ 5873 0 @ 5571 1550.4 1618.36 PSI DRILLING MUD REPORT DEPTH 5862' MW 9.4 VIS 48 PV 15 YP 19 FL 5.0 Gels 6/7/8 CL- 11000 FC 1/3 SOL 5.5 SD 0.5 OIL 0.5/93 MBT 5 pH 9.0 Ca+ 200 Alk 0.55 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 651 @ 5700. 13 @ 5488 97.1 TRIP GAS 828u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 160191 @ 5700 2612 @ 5488 19468.1 CONNECTION GAS HIGH ETHANE (C-2) 582 @ 5700 0 @ 5689 79.1 AVG PROPANE (C-3) 181 @ 5700 0 @ 5729 3.3 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 30u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone/sand, tuffaceous/carbonaceous siltstone/claystone, coals PRESENT LITHOLOGY Tuffaceous sandstone/sand, tuffaceous siltstone DAILY ACTIVITY SUMMARY Hang electrical service loop at top drive; rig up electrical lines to top drive and in derrick; test run; secure service loops. Make up BHA #2; fill mud line; check BHA tools. Trip in hole from 655’ to 3454’; circulate bottoms up at shoe. Trip in hole to 5380’; tight spots at 4650’ and 5000’; trip in to 5470’ rotating; circulate bottoms up and work gas out. Drill from 5486’ to 5863’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 15, 2013 DEPTH 6764' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 5863' 24 HOUR FOOTAGE 901' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6856.86' 13.21 169.26 6670.89' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 TFA=0.835 5486' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 141.0 @ 5946 2.7 @ 6077 78.6 70.23 FT/HR SURFACE TORQUE 22651 @ 6615 27 @ 6439 18483.9 18743.67 AMPS WEIGHT ON BIT 32 @ 6148 0 @ 6535 9.5 8.70 KLBS ROTARY RPM 146 @ 6294 0 @ 5956 115.9 125.87 RPM PUMP PRESSURE 1757 @ 6248 603 @ 6747 1596.7 1582.56 PSI DRILLING MUD REPORT DEPTH 6811' MW 9.3 VIS 47 PV 16 YP 23 FL 5.8 Gels 6/9/12 CL- 11000 FC 1/3 SOL 5 SD 0.75 OIL 1/93 MBT 6 pH 9.1 Ca+ 240 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 584 @ 6048 3 @ 6605 106.0 TRIP GAS 142u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 147741 @ 6048 756 @ 6605 22819.3 CONNECTION GAS HIGH ETHANE (C-2) 618 @ 6298 2 @ 6605 114.1 AVG PROPANE (C-3) 194 @ 6033 0 @ 6205 18.8 CURRENT BUTANE (C-4) 93 @ 6291 2 @ 6303 0.8 CURRENT BACKGROUND/AVG 60u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous siltstone/claystone, tuffaceous sandstone/sand/conglomeratic sand, coal/carbonaceous siltstone PRESENT LITHOLOGY Sand/tuffaceous sandstone/conglomeratic sand DAILY ACTIVITY SUMMARY Drill from 5863’-6438’; pump high vis sweep. Trip out of hole from 6438’; tight spot at 6110’; wash tight spot from 6110’ to 6043’; back ream from 6043’ to 6023’; trip out of hole from 6263’ to 5463’. Trip in hole from 5463’ to 6346’; ream and wash from 6346’ to 6438’. Drill from 6438’ to 6636’. Dump sand trap; change shaker screens; clean possum belly; replace shaker rubbers. Drill from 6636’ to 6764’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 16, 2013 DEPTH 7428' PRESENT OPERATION Tripping in TIME 24:00 YESTERDAY 6764' 24 HOUR FOOTAGE 664' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7340.16' 13.16 164.09 7141.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 TFA=0.835 5486' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 192.0 @ 7308 1.6 @ 7075 74.1 73.77 FT/HR SURFACE TORQUE 24351 @ 6958 17 @ 7213 20222.8 19351 AMPS WEIGHT ON BIT 31 @ 7116 0 @ 7281 9.5 5.97 KLBS ROTARY RPM 148 @ 7335 0 @ 7213 118.2 137.18 RPM PUMP PRESSURE 1822 @ 7426 452 @ 7428 1559.3 452.72 PSI DRILLING MUD REPORT DEPTH 7429' MW 9.35 VIS 51 PV 14 YP 18 FL 5.6 Gels 4/7/9 CL- 11500 FC 1/3 SOL 5 SD 0.75 OIL 1/93 MBT 6 pH 9.0 Ca+ 100 Alk 0.55 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 517 @ 6793 17 @ 7407 93.7 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 114178 @ 6793 3309 @ 7426.00000 19383.2 CONNECTION GAS HIGH ETHANE (C-2) 498 @ 7132 0 @ 7399.00000 110.9 AVG PROPANE (C-3) 115 @ 7234 0 @ 7399.00000 14.3 CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone/conglomeratic sand, tuffaceous siltstone/claystone/shale, coal/carbonaceous siltstone PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill from 6764’ to 7171’. Mud pump 2 shut down; trip out of hole one stand while troubleshooting pump; change shaker screen; tighten hydraulic fitting on top drive; trip back to bottom. Drill from 7171’ to 7428’. Pump sweep for short trip; mud pump 1 down due to liner seal and discharge screen failure; reciprocate from 7311’ to 7408’. Trip out of hole to 6910’; back ream rotating and pumping to 6378’. Trip in hole from 6378’ to 7311’; wash down to 7408’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 17, 2013 DEPTH 8448' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 7428' 24 HOUR FOOTAGE 1020' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8399.25' 12.85 163.09 8173.33' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 TFA=0.835 5486' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 182.1 @ 7503 1.0 @ 7546 67.4 25.13 FT/HR SURFACE TORQUE 46960 @ 8179 5 @ 7791 22489.1 23849.02 AMPS WEIGHT ON BIT 49 @ 8277 0 @ 7990 10.0 10.97 KLBS ROTARY RPM 400 @ 8179 0 @ 7598 117.8 112.74 RPM PUMP PRESSURE 1922 @ 8372 452 @ 7428 1696.5 1796.12 PSI DRILLING MUD REPORT DEPTH 8463' MW 9.45 VIS 47 PV 13 YP 18 FL 6 Gels 5/7/9 CL- 11000 FC 1/3 SOL 5.5 SD 0.75 OIL 1/92.5 MBT 6 pH 9.1 Ca+ 80 Alk 0.45 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 555 @ 7822 10 @ 7939 99.7 TRIP GAS 262 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 116839 @ 7822 1993 @ 7939 20062.8 CONNECTION GAS HIGH 153 ETHANE (C-2) 677 @ 8208 1 @ 8013 129.9 AVG PROPANE (C-3) 170 @ 8208 0 @ 8013 21.1 CURRENT 0 BUTANE (C-4) 50 @ 7454 3 @ 7458 0.2 CURRENT BACKGROUND/AVG 55 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone/sand/conglomeratic sand; tuffaceous siltstone/claystone; coal/carbonaceous siltstone PRESENT LITHOLOGY Tuffaceous sandstone/conglomeratic sand; tuffaceous/carbonaceous/shaly siltstone DAILY ACTIVITY SUMMARY Drill from 7429’ to 7642’; service swivel package on top; check discharge screen #2 mud pump; mix mud; drill from 7642’ to 7790’. Tighten up suction/discharge pod on #1 mud pump; circulate with #2 pump and work pipe. Drill from 7790’ to 8180’. Repair hole in hopper; mix mud; service top drive; grease swivel package and inspect top drive for flow. Drill from 8180’ to 8448’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 18, 2013 DEPTH 9023' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 8448' 24 HOUR FOOTAGE 575' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8977.23' 17.12 212.20 8732.50' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 TFA=0.835 5486' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 112.2 @ 8599 0.5 @ 8914 51.1 42.15 FT/HR SURFACE TORQUE 46842 @ 8852 8 @ 8656 23982.1 22648.78 AMPS WEIGHT ON BIT 36 @ 8851 0 @ 8666 10.1 7.37 KLBS ROTARY RPM 399 @ 8852 0 @ 8656 118.3 113.91 RPM PUMP PRESSURE 1969 @ 9010 1329 @ 8987 1802.8 1905.46 PSI DRILLING MUD REPORT DEPTH 9034' MW 9.45 VIS 48 PV 16 YP 20 FL 5.4 Gels 5/7/10 CL- 11000 FC 1/3 SOL 5.5 SD 0.75 OIL 1/92.5 MBT 6 pH 9.0 Ca+ 100 Alk 0.45 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 455 @ 8891 10 @ 8586 86.7 TRIP GAS 296 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 88963 @ 8891 1843 @ 8586 16722.3 CONNECTION GAS HIGH ETHANE (C-2) 983 @ 8891 20 @ 8586 155.0 AVG PROPANE (C-3) 252 @ 8891 0 @ 8558 38.4 CURRENT BUTANE (C-4) 65 @ 8891 0 @ 8922 2.0 CURRENT BACKGROUND/AVG 50 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous/carbonaceous siltstone/claystone, tuffaceous sandstone/sand/conglomeratic sand, coal PRESENT LITHOLOGY Tuffaceous/carbonaceous siltstone, tuffaceous sandstone/sand, coal DAILY ACTIVITY SUMMARY Drill from 8448’ to 8463’. Circulate and condition hole for short trip; short trip from 8463’ to 7548’; several tight spots. Trip in hole from 7548’; ream with one pump to 8180’; trip in hole to 8371’; ream to bottom. Drill from 8463’ to 8945’. Service top drive; grease swivel package, inspect. Drill from 8945’ to 9023’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Nov 19, 2013 DEPTH 9513' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9023' 24 HOUR FOOTAGE 490' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9458.83' 25.00' 222.37 9178.69' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 TFA=0.835 5486' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 97.9 @ 9432 0.6 @ 9056 38.2 53.96 FT/HR SURFACE TORQUE 30692 @ 9395 1 @ 9427 24855.7 25044.93 AMPS WEIGHT ON BIT 20 @ 9234 0 @ 9512 8.4 1.18 KLBS ROTARY RPM 156 @ 9360 0 @ 9234 117.5 115.58 RPM PUMP PRESSURE 2211 @ 9512 715 @ 9238 1933.4 2211.10 PSI DRILLING MUD REPORT DEPTH 9481' MW 9.5 VIS 53 PV 20 YP 23 FL 4 Gels 5/6/8 CL- 11000 FC 1/2 SOL 5.8 SD 0.75 OIL 0.5/93 MBT 6 pH 9.8 Ca+ 40 Alk 1.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 444 @ 9506 2 @ 9500 143.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 82714 @ 9506 386 @ 9500 17927.9 CONNECTION GAS HIGH 100 ETHANE (C-2) 6996 @ 9220 4 @ 9500 1346.1 AVG 95 PROPANE (C-3) 7563 @ 9220 1 @ 9500 1297.4 CURRENT 0 BUTANE (C-4) 4517 @ 9220 0 @ 9500 691.7 CURRENT BACKGROUND/AVG 45 PENTANE (C-5) 1907 @ 9220 0 @ 9500 331.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9115'-9280' Tuffaceous sandstone/sand See Show Report #1 LITHOLOGY Tuffaceous sandstone/sand/conglomeratic sand; tuffaceous/carbonaceous siltstone; coal PRESENT LITHOLOGY Tuffaceous/carbonaceous siltstone; tuffaceous sandstone/sand; coal DAILY ACTIVITY SUMMARY Drill from 9023’ to 9238’. Mud pump 2 tripped offline; 3 times for a total of 30 min; adjust brushes. Drill from 9238’ to 9513’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 20, 2013 DEPTH 9522' PRESENT OPERATION Rig service TIME 24:00 YESTERDAY 9513' 24 HOUR FOOTAGE 9' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9458.83' 25.00 222.37 9178.69' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 12-1/4" Smith MDSi716 PDC JF9942 9x11/ 0.835 5486' 9522' 4036' 83.9 1-1-CT-N-X-I-PN BOP test DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 61.5 @ 9514 37.5 @ 9516 52.9 41.04 FT/HR SURFACE TORQUE 26983 @ 9519 23341 @ 9520 27825.0 24877.59 AMPS WEIGHT ON BIT 4 @ 9520 1 @ 9513 3.8 4.018 KLBS ROTARY RPM 124 @ 9517 109 @ 9519 130.4 114.18 RPM PUMP PRESSURE 2219 @ 9515 2172 @ 9522 2439.5 2172.73 PSI DRILLING MUD REPORT DEPTH 9522' MW 9.5 VIS 70 PV 22 YP 27 FL 4.2 Gels 5/7/9 CL- 11000 FC 1/2 SOL 5.4 SD 0.5 OIL 0.1/93.5 MBT 7.5 pH 11.0 Ca+ 40 Alk 3.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 211 @ 9516 138 @ 9513 207.9 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 39049 @ 9516 25881 @ 9513 34942.8 CONNECTION GAS HIGH ETHANE (C-2) 387 @ 9516 265 @ 9513 341.2 AVG PROPANE (C-3) 166 @ 9521 85 @ 9513 130.6 CURRENT BUTANE (C-4) 66 @ 9516 12 @ 9520 36.7 CURRENT BACKGROUND/AVG PENTANE (C-5) 8 @ 9513 3 @ 9515 2.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous/carbonaceous siltstone, coal, sand/tuffaceous sandstone PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill from 9513’ to 9522’. Pump sweep; wash out of hole from 9522’ to 8155’; pump dry job; blow down mud line, standpipe, and top drive for freeze protection; trip out of hole to shoe at 3533’; circulate bottoms up; spot pill; flow check; fill trip tank. Service top drive. Trip out from shoe; shut down twice due to platform electrical issues; close blind rams; clean rig floor. Electrician troubleshooting turbine. Pick up swizzle stick assembly; prepare to rinse stack. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 21, 2013 DEPTH 9522' PRESENT OPERATION Thawing/maintenance TIME 24:00 YESTERDAY 9522' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9522' MW 9.4 VIS 68 PV 19 YP 18 FL 4.4 Gels 5/6/8 CL- 11000 FC 1/2 SOL 5.2 SD 0.5 OIL 1/92.8 MBT 7.5 pH 10.5 Ca+ 40 Alk 1.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run BOP wash tool to wear ring; rig up air line and confirm 4” mud line open to mud pumps; confirm top drive, mud line, and stand pipe open. Filled flow box with mud, ran over beam and out between rig and utility module; clean up; clean mud/cuttings from flow box; clean mud under rig floor. Flush BOP stack; function rams and flush again; lay down wash tool; stand back one stand; drain BOP stack to trip tank. Make up test assembly and pull wear ring; set test plug; make up pump in sub, floor safety valve, dart valve; rig up hoses. Working on low torque valve for kill line on rig floor; suspect frozen—okay; valve working. Lost power to rig. Fill stack with water; thaw out gas buster drain. Test annular, rig floor kill line valve, upper IBOP, choke valves, VBR, kill HCR, dart valve, and floor safety valve. Drawdown; choke HCR; lower P/R. Monitor well. Test blind rams. Lay down test plug; install wear ring. Blow down kill and choke manifold; remove Kelly hose and thaw; thaw frozen top drive; thaw gas buster; thaw lines between RPM and utility modules; reinstall Kelly hose. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 22, 2013 DEPTH 9522' PRESENT OPERATION Tripping in TIME 24:00 YESTERDAY 9522' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 5922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9522' MW 9.5 VIS 58 PV 17 YP 13 FL 4.0 Gels 4/5/6 CL- 11000 FC 1/2 SOL 5.5 SD 0.5 OIL 0.5/93 MBT 7.5 pH 10.6 Ca+ 40 Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 768 @ shoe CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Secure service loop hoses in derrick; blow down choke manifold; lay down 20’ pup and one joint drillpipe; clear floor; bleed 10 psi from well. Pick up BHA; trip in hole to 3440’; circulate four bottoms up. Monitor well for 30 min; test all gas alarms; install deflector guard on tong bucket for service loop; reinstall pull back mule at derrick board. Break out top drive; install safety valve; recharge top drive compensator; install hoist for stabbing board; shrader valve leaked on compensator; replace shrader valve; grease crown and blocks; assist crane crew with drillpipe onto deck. Changeout lower IBOP and saversub; clean mud product from drums for shipping; clean decks and RPM module. Test lower IBOP; blow down choke and top drive; drain poor boy. Pick up torque reducers; changeout floor equipment. Pick up 12 joints drillpipe; trip in hole adding torque reducers to 3 singles; stand back; trip in with stands from offdriller side installing torque reducers; change tally. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 23, 2013 DEPTH 9522' PRESENT OPERATION Tripping in TIME 24:00 YESTERDAY 9522' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9522' MW 9.5 VIS 60 PV 20 YP 16 FL 3.7 Gels 3/5/6 CL- 11000 FC 1/2 SOL 6.3 SD 0.25 OIL 0.5/92.2 MBT 6 pH 9.8 Ca+ 40 Alk 1.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS see below CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Trip in; install one NRTR per joint, 14 joints total. Circulate bottoms up @ 3440’; 526u gas. Test 4” mud line to IBOP valve; union leaked; blow down top drive; replace mud line seal rubber; retest to 3500 psi; blow down top drive and mud line. Trip in hole; tag at 4606’; wash to 4656’; gas to 1768u; circulate until down to 150u. Weight indicator not working; wash out of hole to 3490’; hang blocks/top drive; remove drilling line from tie down; change out bad load cell for weight indicator; put drilling line back on deadman; blow down top drive and mud line. Trip back in hole; wash through tight spot at 5020’; gas 668u; trip to 5475’. Trip to 6070’; gas 471u and 716u. Lost power due to intakes packed with snow. Trip in to 7000’; gas 426u. Trip in to 7880’ installing NRTRs. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 24, 2013 DEPTH 9629' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9522' 24 HOUR FOOTAGE 107' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9556.93' 26.20 222.91 9266.93' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 42.1 @ 9558 0.9 @ 9592 15.0 2.57 FT/HR SURFACE TORQUE 23507 @ 9575 7 @ 9524 20698.9 21089.33 AMPS WEIGHT ON BIT 18 @ 9529 3 @ 9588 10.7 15.84 KLBS ROTARY RPM 144 @ 9625 0 @ 9526 115.6 118.27 RPM PUMP PRESSURE 2113 @ 9624 7 @ 9527 1864.9 2063.39 PSI DRILLING MUD REPORT DEPTH 9625' MW 9.8 VIS 59 PV 20 YP 21 FL 4.0 Gels 5/7/10 CL- 11000 FC 1/2 SOL 7.6 SD 0.25 OIL 0.5/91 MBT 6 pH 9.8 Ca+ 80 Alk 1.2 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 239 @ 9525 31 @ 9629 95.1 TRIP GAS 1038 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 44516 @ 9525 4801 @ 9629 14243.6 CONNECTION GAS HIGH ETHANE (C-2) 1989 @ 9588 105 @ 9629 703.5 AVG PROPANE (C-3) 1951 @ 9588 83 @ 9629 635.2 CURRENT BUTANE (C-4) 1076 @ 9588 56 @ 9528 390.0 CURRENT BACKGROUND/AVG 50 PENTANE (C-5) 415 @ 9588 26 @ 9528 168.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand/tuffaceous sandstone; tuffaceous/carbonaceous/shaly siltstone; coal PRESENT LITHOLOGY Tuffaceous sandstone; tuffaceous/carbonaceous/shaly siltstone DAILY ACTIVITY SUMMARY Circulate bottoms up at 7880’. Trip in to 9527’ rotating and pumping. Drill from 9527’ to 9574’. Circulate and condition; mud pump 2 overheating with electrical issues. Drill from 9574’ to 9625’. Increase mud weight to 9.9 ppg; troubleshoot mud pump 2. Drill from 9625’ to 9629’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 25, 2013 DEPTH 9833' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9629' 24 HOUR FOOTAGE 204' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9749.36' 29.93 222.85 9436.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 51.0 @ 9637 0.9 @ 9690 14.0 4.70 FT/HR SURFACE TORQUE 24710 @ 9701 28 @ 9816 21714.1 20406.98 AMPS WEIGHT ON BIT 15 @ 9629 0 @ 9668 9.7 12.47 KLBS ROTARY RPM 144 @ 9766 0 @ 9816 125.1 133.77 RPM PUMP PRESSURE 2079 @ 9717 917 @ 9650 1903.7 1927.20 PSI DRILLING MUD REPORT DEPTH 9833' MW 10.0 VIS 60 PV 26 YP 25 FL 3.4 Gels 4/6/8 CL- 11000 FC 1/2 SOL 8.7 SD 0.25 OIL 0.5/89.9 MBT 6 pH 9.5 Ca+ 40 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 382 @ 9685 36 @ 9635 126.0 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 40277 @ 9685 5030 @ 9635 14914.8 CONNECTION GAS HIGH ETHANE (C-2) 4352 @ 9685 93 @ 9635 862.9 AVG PROPANE (C-3) 4281 @ 9686 49 @ 9820 790.7 CURRENT BUTANE (C-4) 2407 @ 9686 49 @ 9643 561.9 CURRENT BACKGROUND/AVG 45 PENTANE (C-5) 877 @ 9702 29 @ 9648 268.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone/conglomeratic sand; tuffaceous/carbonaceous siltstone; coal PRESENT LITHOLOGY Tuffaceous/carbonaceous siltstone/claystone; tuffaceous sandstone/sand DAILY ACTIVITY SUMMARY Drill from 9629’ to 9716’. Mud pump 2 continues kicking off; work pipe; adjust belts on mud pump 2; pump stopped kicking off. Drill from 9716’ to 9778’. Circulate and condition; up mud weight to 10 ppg; tighten belts on mud pump 2; change out suction; service top drive. Drill from 9778’ to 9833; increase mud weight to 10.2 ppg. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetsir DATE Nov 26, 2013 DEPTH 10123' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 9833' 24 HOUR FOOTAGE 290' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10038.64' 36.32 227.56 9679.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 80.1 @ 10105 0.5 @ 9869 19.6 15.06 FT/HR SURFACE TORQUE 24353 @ 10026 38 @ 10007 21103.1 22472.78 AMPS WEIGHT ON BIT 23 @ 10009 0 @ 10109 9.6 18.07 KLBS ROTARY RPM 149 @ 9892 0 @ 10008 131.9 137.57 RPM PUMP PRESSURE 2148 @ 9873 1344 @ 10104 2041.1 1978.69 PSI DRILLING MUD REPORT DEPTH 10128' MW 10.15 VIS 58 PV 21 YP 21 FL 4.0 Gels 5/7/9 CL- 11000 FC 1/2 SOL 8.3 SD 0.25 OIL 0.5/90.3 MBT 6 pH 9.3 Ca+ 40 Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 390 @ 10080 20 @ 9894 86.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 39881 @ 10080 2327 @ 9928 9194.3 CONNECTION GAS HIGH 82 ETHANE (C-2) 6312 @ 10080 89 @ 9849 842.7 AVG PROPANE (C-3) 3741 @ 10041 34 @ 9849 808.7 CURRENT BUTANE (C-4) 2562 @ 10079 2 @ 9898 600.9 CURRENT BACKGROUND/AVG 55 PENTANE (C-5) 1404 @ 10079 1 @ 9872 312.8 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9920'-10075' Conglomeratic sand/tuffaceous sandstone 257u See Show Report #2 LITHOLOGY Tuffaceous/carbonaceous/shaly siltstone/claystone; conglomeratic sand/tuffaceous sandstone; coal PRESENT LITHOLOGY Tuffaceous siltstone/claystone; conglomeratic sand/tuffaceous sandstone DAILY ACTIVITY SUMMARY Drill from 9833’ to 9870’. Work on mud pump 2, still kicking off; work pipe. Drill from 9870 to 10006’. Service top drive; grease wash pipe; monitor electrical synchronization of traction motor for mud pump 2; change shaker screens, flush possum belly and flow line; clean centrifuge. Drill from 10006’ to 10123’; performed kick while drilling drill. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 27, 2013 DEPTH 10356' PRESENT OPERATION Drilling TIME 24:00 YESTERDAY 10123' 24 HOUR FOOTAGE 233' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10328.20' 40.34 233.24 9907.30' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 53.4 @ 10297 0.5 @ 10315 14.6 10.09 FT/HR SURFACE TORQUE 27259 @ 10258 27 @ 10297 20910.6 21261.00 AMPS WEIGHT ON BIT 27 @ 10276 4 @ 10136 15.0 18.71 KLBS ROTARY RPM 166 @ 10264 0 @ 10298 143.6 144.82 RPM PUMP PRESSURE 2230 @ 10322 1095 @ 10313 1958.4 1988.92 PSI DRILLING MUD REPORT DEPTH 10366' MW 10.1 VIS 57 PV 21 YP 23 FL 3.8 Gels 6/8/10 CL- 11000 FC 1/2 SOL 8.6 SD 0.25 OIL 0.5/90 MBT 6 pH 9.3 Ca+ 40 Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 319 @ 10335 16 @ 10193 57.6 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 61529 @ 10335 2910 @ 10148 9841.3 CONNECTION GAS HIGH 29u ETHANE (C-2) 788 @ 10335 46 @ 10148 174.5 AVG PROPANE (C-3) 269 @ 10335 28 @ 10218 79.1 CURRENT BUTANE (C-4) 172 @ 10123 1 @ 10214 47.0 CURRENT BACKGROUND/AVG 45u PENTANE (C-5) 184 @ 10123 1 @ 10214 15.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10150'-10220' Tuffaceous sandstone 65u See Show Report #3 LITHOLOGY Tuffaceous sandstone/sand; tuffaceous/carbonaceous siltstone/claystone; coal PRESENT LITHOLOGY Tuffaceous/carbonaceous siltstone/claystone; sand/tuffaceous sandstone DAILY ACTIVITY SUMMARY Drill from 10123’ to 10199’. Trip out of hole to 10010’; electrician changing out boards on pump; trip back to bottom. Drill from 10199 to 10356’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 28, 2013 DEPTH 10560' PRESENT OPERATION Tripping out TIME 24:00 YESTERDAY 10356' 24 HOUR FOOTAGE 204' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10492.41' 43.64 235.29 10029.07' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 39.6 @ 10407 0.7 @ 10396 18.1 5.17 FT/HR SURFACE TORQUE 25539 @ 10506 17449 @ 10542 21686.6 21532.21 AMPS WEIGHT ON BIT 30 @ 10488 4 @ 10410 19.8 27.84 KLBS ROTARY RPM 165 @ 10542 122 @ 10488 147.2 144.85 RPM PUMP PRESSURE 2136 @ 10385 1833 @ 10393 2012.6 2062.31 PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 57 PV 22 YP 22 FL 3.8 Gels 6/8/10 CL- 11000 FC 1/2 SOL 9.1 SD 0.25 OIL 0.5/89.5 MBT 6 pH 9.5 Ca+ 80 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 398 @ 10414 32 @ 10552 69.3 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 70092 @ 10414 5193 @ 10431 11720.2 CONNECTION GAS HIGH 47 ETHANE (C-2) 2054 @ 10436 102 @ 10527 301.9 AVG PROPANE (C-3) 2228 @ 10436 32 @ 10527 166.8 CURRENT BUTANE (C-4) 1256 @ 10436 2 @ 10391 124.2 CURRENT BACKGROUND/AVG PENTANE (C-5) 437 @ 10436 11 @ 10553 56.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous/carbonaceous siltstone/claystone; tuffaceous sandstone/conglomeratic sand; coal PRESENT LITHOLOGY Tuffaceous/carbonaceous siltstone/claystone; tuffaceous sandstone/sand; coal DAILY ACTIVITY SUMMARY Drill from 10356’ to 10560’. Circulate and condition; check for flow. Trip out of hole from 10560’ to 4830’; blow down Kelly and hard lines to mud pumps; fill it. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,710, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 29, 2013 DEPTH 10560' PRESENT OPERATION Wiper trip TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 57 PV 22 YP 21 FL 3.8 Gels 5/8/10 CL- 11000 FC 1/2 SOL 8.3 SD 0.25 OIL 0.5/90.3 MBT 6 pH 9.5 Ca+ 80 Alk 0.7 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 675 & 497 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Trip out from 4830’ to 3454’ rotating from 4520’ to 4000’, pumping out from 4000’ to 3800’, and pulling dry from 3800’ to 3454’; circulate bottoms up at 3454’. Blow down top drive; monitor well; move Kelly hose to behind service loop; slip and cut drilling line; adjust brakes; grease crown, draw works, and top drive; check oil in top drive, was overfilled, drain two gallons; remove hang line; move top drive to check Kelly hose; adjust brakes again; pressure test Kelly hose and blow down top drive to mud pumps. Trip in from 3450’ to 10560’; 675u gas while circulating at 9271’; tagged fill at 10552’; 497u gas while circulating at 10560’. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Nov 30, 2013 DEPTH 10560' PRESENT OPERATION Cleaning BOP stack TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 12-1/4" Smith MDSi716 PDC JF9942 9x11 9522' 10560' 1038' 77.2 2-3-CT-A-X-IN-PN TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.2 VIS 50 PV 16 YP 18 FL 4.0 Gels 7/9/11 CL- 11000 FC 1/2 SOL 8.3 SD 0.25 OIL 0.5/90.3 MBT 6 pH 9.5 Ca+ 40 Alk 1.0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Work pipe from 10550’ to 10461’; pump sweep; circulate 14000 strokes. Trip out of hole on elevators from 10550’ to shoe at 3544’; monitor well for flow, static; circulate bottoms up at shoe; pump dry job. Trip out of hole; change out jars; stand back HWDP, flex collars; break off bit; lay down BHA; clear rig floor; lift subs. Change elevators; pick up one joint DP; make up wash tool and crossover; wash BOP stack. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Dec 1, 2013 DEPTH 10560' PRESENT OPERATION Running 9-5/8" casing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 51 PV 15 YP 20 FL 4.0 Gels 5/7/9 CL- 11000 FC 1/2 SOL 8.1 SD 0.25 OIL 0.5/90.5 MBT 6 pH 9.5 Ca+ 40 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Clean stack; clean under stripping rubber catch pan and rig floor; remove wear ring for casing run. Pick up test tools; make up 9-5/8” test joint; change bottom rams to 9-5/8”; 9-5/8” BOP test failed; changed test joint to seal on a different spot; could not test; rebuild 9-5/8” rams; change out rubber; fix hydraulic leak on door; reinstall 9-5/8” rams; recharge Koomey unit and fill stack with water; test 9-5/8” rams to 3000 psi. Blow down top drive, mud line; rig down test hoses; lay down testing assembly. Clean up pits and mud from trip out. Lay down 5-1/2” elevators and bails. Move CRT to rig floor; make up to top drive; rig up wotco to run 9-5/8” casing; CRT, tongs, spider, and safety valve. Pick up 9-5/8” shoe joint; move centralizer and top rings to 10’ above shoe; trip in hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sweetsir DATE Dec 2, 2013 DEPTH 10560' PRESENT OPERATION Running 9-5/8" casing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 48 PV 15 YP 15 FL 4.5 Gels 5/7/9 CL- 11000 FC 1/2 SOL 8.1 SD 0.25 OIL 0.5/90.5 MBT 6 pH 9.6 Ca+ 80 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 186 & 317 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PJSM for sunning 9-5/8” casing and CRT operation. Make up the first three joints with baker lock and pump; returns to shakers; check float equipment. Run casing to 3502’; pump bottoms up, 186u gas; circulate while offloading 99 joints casing from boat; run casing in to 5075’; pump bottoms up, 317u gas; run casing to 5373’; 132 joints in hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,210, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 3, 2013 DEPTH 10560' PRESENT OPERATION Cementing TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 42 PV 13 YP 16 FL 4.8 Gels 7/8/9 CL- 11000 FC 1/2 SOL 8.1 SD 0.25 OIL 0.5/90.5 MBT 5 pH 6.8 Ca+ 80 Alk 0.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 537 & 485 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Run casing from 5373’ to 7510’; fill on every sixth joint running in; work pipe and pump, max gas 537u; run casing to 10422’; make up hanger and landing joint; circulate two bottoms up, max gas 485u; work down to 10480’ while circulating; attempted to reciprocate and could not pick up; land 9-5/8” casing at 10483’; set in hanger. Release CRT from landing joint; blow down CRT and top drive. Rig up cementing head, lines, and valves; circulate through cementing head. PJSM for cement job. SLB pump 5 bbl water; test lines to 5000 psi; rig pump 40 bbl 10.5 ppg mud push; chase with 8 bbl mud; SLB drop bottom plug while started pumping cement; SLB pump 450 bbl 12.5 ppg lead cement; follow with 43.5 bbl 15.8 ppg tail cement; SLB drop top plug and chase with 5 bbl water. Rig displace with 10.1 ppg mud; 650 bbl away. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: $3,010, RW: $1,780 REPORT BY Hammond Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 4, 2013 DEPTH 10560' PRESENT OPERATION n/d BOP's TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 9.9 VIS 449 PV 13 YP 12 FL 5.8 Gels 7/9/10 CL- 10500 FC 1/2 SOL 6.1 SD 0.25 OIL 0.5/92.5 MBT 5 pH 8.7 Ca+ - Alk 0.35 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Displace cement with 10.1ppg mud. took 766 bbls to bump plug to 1300 psi. Bleed down casing and had 3.5 bbls return. Test casing on chart for 30 min to 1500 psi. Blow down all lines and R/D casing/cementing equipment. clean and clear rig floor. Pick bails up and and put elevators on. P/U BHA with 4 stands of HWDP and RTTS. RTTS would not makke up. Break connection and clear tool. M/U 9 5/8" RTTS to 5 1/2" DP. TIH and set RTTS @ 96'. TIH LD RNG tool stand back DP. Pressure test down to RTTS @1500 psi for 15 min. ok. Bleed off pressure and BD mud lines. P/U 1 std 5 1/2" DP. TIH and L/D top single. R/U head pin and valve hose. Flush BOP stack and drain down below 9 5/8" hanger. R/D head pin, valve, hose and stand back in derrick. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: $3,010, RW: $1,780 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 5, 2013 DEPTH 10560' PRESENT OPERATION Rig Service TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 9.9 VIS 50 PV 12 YP 14 FL 5.8 Gels 7/9/10 CL- 10500 FC 1/2 SOL 6.1 SD 0.25 OIL 0.5/92.5 MBT 5 pH 8.5 Ca+ 80 Alk 0.30 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue nippling up BOP's while performing miscellaneous rig maintenance and installing iron roughneck. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: $3,010, RW: $1,780 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 6, 2013 DEPTH 10560' PRESENT OPERATION Rig Service TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 9.9 VIS 50 PV 12 YP 14 FL 5.5 Gels 7/8/10 CL- 10500 FC 1/2 SOL 6.1 SD 0.25 OIL 0.5/92.5 MBT 5 pH 9.0 Ca+ 120 Alk 0.25 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish installing iron roughnreck, continue rig maintenance and prep for BOP's test. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: $3,010, RW: $1,780 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 7, 2013 DEPTH 10560' PRESENT OPERATION Rig Service TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 9.9 VIS 52 PV 13 YP 15 FL 4.6 Gels 6/8/9 CL- 10000 FC 1/2 SOL 6.1 SD - OIL 0.5/92.5 MBT 4 pH 8.6 Ca+ 120 Alk 0.15 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY P/U test joint and R/u to test BOP's. L/D test joint and R/D BOP testing equipment. Take on DP and continue rig service. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: $3,010, RW: $1,780 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 8, 2013 DEPTH 10560' PRESENT OPERATION Tripping in TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10,560' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 55 PV 15 YP 17 FL 7.5 Gels 7/12/15 CL- 10000 FC 1/2 SOL 8.6 SD 0.25 OIL 0.5/90.0 MBT 6 pH 6.4 Ca+ 640 Alk - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue with rig service. P/U BHA #4 and TIH. Shallow test MWD tools and continue TIH. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML: $3,010, RW: $1,780 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 9, 2013 DEPTH 10560' PRESENT OPERATION Runing in hole TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10,560' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 48 PV 14 YP 16 FL 7.2 Gels 6/8/10 CL- 9000 FC 1/0 SOL 8.2 SD 0.15 OIL 0.5/90.5 MBT 4.5 pH 7.2 Ca+ 240 Alk - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue RIH to 7099' and CBU 3x Slip and cut drill line and service top drive. rack back 6 stands. continue RIH, installing NRP's. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,043, RW: $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 10, 2013 DEPTH 10560' PRESENT OPERATION Runing in hole TIME 24:00 YESTERDAY 10560' 24 HOUR FOOTAGE 0' CASING INFORMATION 13-3/8" @ 3533', 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10,560' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10560' MW 10.1 VIS 50 PV 14 YP 16 FL 7.8 Gels 6/8/10 CL- 9000 FC 1/0 SOL 8.2 SD 0.25 OIL 0.5/90.5 MBT 4.0 pH 6.8 Ca+ 240 Alk - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY RIH to 10,200', installing NRP's. TOOH to 6,720'. Pick up 78 joints of 5.5" DP and rack back 26 stands. Pick up 42 joints 5.5" DP. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,043, RW: $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sun DATE Dec 11, 2013 DEPTH 10739 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 10560 24 HOUR FOOTAGE 179 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" Smith MDSi716 JH5966 3x16, 1x13 10,560' 179' 6.25 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 160 @ 10599 2.7 @ 10692 47.6 37.6 FT/HR SURFACE TORQUE 27788 @ 10632 8 @ 10597 24958.6 25969.6 AMPS WEIGHT ON BIT 43 @ 10602 4 @ 10692 25.0 19.2 KLBS ROTARY RPM 144 @ 10560 0 @ 10597 124.4 140.4 RPM PUMP PRESSURE 2577 @ 10711 8 @ 10597 2033.3 2570.0 PSI DRILLING MUD REPORT DEPTH MW 10.6 VIS 52 PV 20 YP 23 FL 3.6 Gels 13/17/19 CL- 11000 FC 1/2 SOL 10.6 SD 0.25 OIL 0.5/88.0 MBT 5.0 pH 10.0 Ca+ 2400 Alk 0.80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 114 @ 10696 4 @ 10592 20.5 TRIP GAS 541u CUTTING GAS 0 @ 10739 0 @ 10739 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 17719 @ 10696 672 @ 10630 2195.6 CONNECTION GAS HIGH ETHANE (C-2) 652 @ 10653 1 @ 10579 55.7 AVG PROPANE (C-3) 454 @ 10644 0 @ 10579 31.1 CURRENT 15u BUTANE (C-4) 394 @ 10644 2 @ 10621 26.7 CURRENT BACKGROUND/AVG 12u PENTANE (C-5) 192 @ 10644 1 @ 10621 10.9 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone 40% Tuffaceous claystone 30% Tuffaceous siltstone 20% Coal/carb shale 10% PRESENT LITHOLOGY Tuffacous claystone 40% Tuffaceous silttsone 20% Tuffaceous sandstone 20% sand 10% coal/carb shale 10% DAILY ACTIVITY SUMMARY Continue tripping into hole and tag cement. CBU and test casing to 4000 psi. Drill out cement and 20' of new hole. FIT to 15ppg and begin drilling. drilling ahead at 10739' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML: $3,043 RW: $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 12, 2013 DEPTH 11076 PRESENT OPERATION Repair top drive TIME 23:59 YESTERDAY 10739 24 HOUR FOOTAGE 337 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10560' 516' 15.28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 117.6 @ 10885 1.9 @ 10889 44.6 31.74 FT/HR SURFACE TORQUE 46797 @ 10982 5 @ 10789 25286.5 24023.57 AMPS WEIGHT ON BIT 41 @ 10789 1 @ 10884 15.8 16.17 KLBS ROTARY RPM 399 @ 10982 0 @ 10790 142.1 139.04 RPM PUMP PRESSURE 2674 @ 10966 13 @ 10986 2464.2 2403.42 PSI DRILLING MUD REPORT DEPTH 11076' MW 11.15 VIS 54 PV 25 YP 26 FL 4.6 Gels 9/16/20 CL- 10000 FC 1/2 SOL 12.0 SD 0.25 OIL 0.5/86.7 MBT 6.5 pH 9.6 Ca+ 760 Alk 0.70 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 271 @ 10897 2 @ 10755 34.2 TRIP GAS CUTTING GAS 0 @ 11076 0 @ 11076 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 42492 @ 10897 81 @ 10924 5065.7 CONNECTION GAS HIGH 122u ETHANE (C-2) 2327 @ 10911 4 @ 10947 255.0 AVG 65u PROPANE (C-3) 434 @ 10898 0 @ 10833 36.8 CURRENT BUTANE (C-4) 302 @ 10897 0 @ 10833 15.1 CURRENT BACKGROUND/AVG 14u PENTANE (C-5) 132 @ 10897 0 @ 10976 3.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone 40% Tuffaceous siltstone 40% Sand 10% Tuffaceous claystone 10% PRESENT LITHOLOGY Tuffaceous sandstone 40% Tuffaceous siltstone 40% Sand 10% Tuffaceous claystone 10% DAILY ACTIVITY SUMMARY Drilled ahead to 11076'. Top drive fails and pump out two stands before having to shut down top drive and troubleshoot while slow pumping. Inside casing while circulating and weighing up mud. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 13, 2013 DEPTH 11076 PRESENT OPERATION Servicing rig TIME 23:59 YESTERDAY 11076 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10560' 516' 15.28 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.25 VIS 54 PV 29 YP 25 FL 5.0 Gels 8/14/16 CL- 10500 FC 1/2 SOL 16.0 SD 0.15 OIL 0.5/82.7 MBT 6.0 pH 9.8 Ca+ 760 Alk 0.60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY no new footage drilled PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue circulating while repairing top drive. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Dec 14, 2013 DEPTH 11253 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 11076 24 HOUR FOOTAGE 177 CASING INFORMATION 13-3/8" @3533' 9-5/8" @10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16,1x13 10560' 693' 20.65 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 76 @ 11113 1.1 @ 11160 50.1 47.13 FT/HR SURFACE TORQUE 27154 @ 11222 10 @ 11174 24047.7 23638.40 AMPS WEIGHT ON BIT 42 @ 11079 9 @ 11199 17.3 18.14 KLBS ROTARY RPM 156 @ 11157 0 @ 11174 139.2 135.91 RPM PUMP PRESSURE 2814 @ 11160 2160 @ 11233 2690.4 2693.39 PSI DRILLING MUD REPORT DEPTH 11147 MW 12.5 VIS 53 PV 27 YP 24 FL 4.8 Gels 8/14/16 CL- 10000 FC 1/2 SOL 17.3 SD 0.25 OIL 0.5/81.4 MBT 5.5 pH 9.4 Ca+ 320 Alk 0.40 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 176 @ 11114 6 @ 11164 32.0 TRIP GAS 13u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 35617 @ 11114 1091 @ 11086 5020.0 CONNECTION GAS HIGH 8u ETHANE (C-2) 433 @ 11114 1 @ 11191 68.5 AVG 8u PROPANE (C-3) 117 @ 11232 0 @ 11191 11.5 CURRENT BUTANE (C-4) 86 @ 11113 0 @ 11191 8.0 CURRENT BACKGROUND/AVG 12u PENTANE (C-5) 0 @ 11253 0 @ 11253 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone 40% Tuffaceous siltstone 30% Tuffaceous claystone 20% coal 10% PRESENT LITHOLOGY Tuffaceous material/ash 40% tuffaceous sandstone 20% tuffaceous siltstone 20% carbonaceous shale/coal 10% DAILY ACTIVITY SUMMARY Continue circulating above the shoe while repairing top drive. Wash/ream down to TD and begin drilling. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Dec 15, 2013 DEPTH 11629 PRESENT OPERATION Drilling TIME 00:47:26 YESTERDAY 11253 24 HOUR FOOTAGE 376 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10483' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10560' 1069 32.76 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 103.0 @ 11458 2.1 @ 11615 43.9 63.59 FT/HR SURFACE TORQUE 31135 @ 11499 7 @ 11366 23986.1 23064.24 AMPS WEIGHT ON BIT 21 @ 11340 4 @ 11594 14.6 17.44 KLBS ROTARY RPM 157 @ 11485 0 @ 11561 134.8 148.96 RPM PUMP PRESSURE 2943 @ 11501 1907 @ 11451 2710.4 2813.71 PSI DRILLING MUD REPORT DEPTH 11561 MW 12.65 VIS 57 PV 30 YP 30 FL 4.8 Gels 11/20/23 CL- 10000 FC 1/2 SOL 17.7 SD 5.0 OIL 0.5/81.0 MBT 5.0 pH 9.8 Ca+ 80 Alk 0.6 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 278 @ 11423 3 @ 11254 47.9 TRIP GAS CUTTING GAS 0 @ 11629 0 @ 11629 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 54062 @ 11423 265 @ 11406 8468.9 CONNECTION GAS HIGH 43u ETHANE (C-2) 1846 @ 11391 0 @ 11304 284.3 AVG 14u PROPANE (C-3) 2289 @ 11492 0 @ 11304 191.0 CURRENT 8u BUTANE (C-4) 1668 @ 11492 0 @ 11304 126.0 CURRENT BACKGROUND/AVG 21u PENTANE (C-5) 648 @ 11492 1 @ 11532 45.9 HYDROCARBON SHOWS See show report #4 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sand 30% Tuffaceous sandstone 20% Tuffaceous siltstone 20% Tuffaceous claystone 20% coal 10% PRESENT LITHOLOGY Sand 30% coal 30% Tuffaceous sandstone 20% tuffaceous siltstone 10% tuffaceous claystone 10% DAILY ACTIVITY SUMMARY Drilled ahead to 11463' when swivel packing began to leak. Shut down and replaced swivel packing while slow pumping. Continued drilling ahead to 11629' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC gRANITE pOINT fIELD DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Dec 16, 2013 DEPTH 12097 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 11629 24 HOUR FOOTAGE 468 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10560 1537' 49.15 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 129.4 @ 11763 4.1 @ 11997 35.8 24.80 FT/HR SURFACE TORQUE 31354 @ 11909 2 @ 12042 24601.4 25871.54 AMPS WEIGHT ON BIT 23 @ 11655 4 @ 11950 15.9 20.28 KLBS ROTARY RPM 158 @ 11719 0 @ 11850 137.8 144.67 RPM PUMP PRESSURE 2951 @ 11665 2145 @ 12063 2761.4 2704.82 PSI DRILLING MUD REPORT DEPTH 12066 MW 12.7 VIS 60 PV 31 YP 26 FL 5.4 Gels 12/22/25 CL- 11000 FC 1/2 SOL 18.3 SD 0.25 OIL 0.5/80.4 MBT 5.5 pH 9.4 Ca+ 80 Alk 0.50 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 430 @ 11762 4 @ 11888 29.6 TRIP GAS 346u CUTTING GAS 0 @ 12097 0 @ 12097 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 59499 @ 11762 648 @ 11888 5113.0 CONNECTION GAS HIGH 12u ETHANE (C-2) 7478 @ 11991 2 @ 11885 525.5 AVG PROPANE (C-3) 5143 @ 11762 0 @ 11842 269.2 CURRENT BUTANE (C-4) 5182 @ 11762 0 @ 11888 178.4 CURRENT BACKGROUND/AVG 20u PENTANE (C-5) 2420 @ 11762 0 @ 11842 62.2 HYDROCARBON SHOWS See show report #5 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand 50% tuffaceous sandstone 30% siltstone 10% carbonaceous shale/coal 10% PRESENT LITHOLOGY Conglomeratic sand 50% tuffaceous sandstone 30% siltstone 10% carbonaceous shale/coal 10% DAILY ACTIVITY SUMMARY Drilled ahead to 12,041', CBU and perform a short trip to 11075'. Wash and ream back to bottom and begin drilling ahead to 12097' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Dec 17, 2013 DEPTH 12316 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12097 24 HOUR FOOTAGE 219 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10560 1756 64.7 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 42.2 @ 12127 1.4 @ 12212 16.0 17.90 FT/HR SURFACE TORQUE 27067 @ 12208 4 @ 12234 24479.4 25160.34 AMPS WEIGHT ON BIT 26 @ 12294 11 @ 12207 22.0 23.96 KLBS ROTARY RPM 157 @ 12168 0 @ 12139 139.2 143.20 RPM PUMP PRESSURE 2901 @ 12241 1684 @ 12144 2645.0 2739.72 PSI DRILLING MUD REPORT DEPTH 12296 MW 12.95 VIS 49 PV 23 YP 21 FL 3.8 Gels 7/11/15 CL- 11000 FC 1/2 SOL 19.1 SD 0.25 OIL 0.5/79.6 MBL 6.0 pH 9.5 Ca+ 20 CCI 0.80 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 58 @ 12101 3 @ 12232 13.3 TRIP GAS CUTTING GAS 0 @ 12316 0 @ 12316 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7334 @ 12101 268 @ 12167 1999.8 CONNECTION GAS HIGH ETHANE (C-2) 1231 @ 12101 82 @ 12143 342.2 AVG PROPANE (C-3) 971 @ 12101 56 @ 12143 234.4 CURRENT BUTANE (C-4) 619 @ 12101 2 @ 12213 131.4 CURRENT BACKGROUND/AVG 8u PENTANE (C-5) 307 @ 12101 1 @ 12242 41.9 HYDROCARBON SHOWS See show reports #6,7 and 8 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand 80% Tuffaceous sandstone 10% Tuffaceous siltstone 10% PRESENT LITHOLOGY Conglomeratic sand 80% Tuffaceous sandstone 10% Tuffaceous siltstone 10% DAILY ACTIVITY SUMMARY Drilled ahead to 12211' and lost power from production. Fixed power issue and continued drilling ahead to 12316' at report time CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 18, 2013 DEPTH 12493 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12316 24 HOUR FOOTAGE 177 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" SMITH MDSi716 JH5966 3x16, 1x13 10560 1933 82.7 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 33.0 @ 12365 0.8 @ 12432 12.3 4.93 FT/HR SURFACE TORQUE 28437 @ 12437 2 @ 12331 25330.5 27081.88 AMPS WEIGHT ON BIT 27 @ 12491 9 @ 12428 21.8 26.19 KLBS ROTARY RPM 149 @ 12401 106 @ 12437 132.2 137.36 RPM PUMP PRESSURE 2852 @ 12335 1723 @ 12323 2608.4 2760.17 PSI DRILLING MUD REPORT DEPTH 12490 MW 12.95 VIS 47 PV 26 YP 14 FL 3.8 Gels 7/11/15 CL- 11000 FC 1/2 SOL 19.1 SD 0.25 OIL 0.5/79.6 MBL 6.0 pH 9.7 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 25 @ 12351 2 @ 12493 7.6 TRIP GAS CUTTING GAS 0 @ 12493 0 @ 12493 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 6409 @ 12367 561 @ 12478 1680.7 CONNECTION GAS HIGH ETHANE (C-2) 1289 @ 12351 99 @ 12478 315.2 AVG PROPANE (C-3) 1035 @ 12351 62 @ 12493 228.7 CURRENT BUTANE (C-4) 656 @ 12351 2 @ 12362 134.1 CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 380 @ 12439 2 @ 12362 101.8 HYDROCARBON SHOWS See show report #9 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand 100% PRESENT LITHOLOGY Conglomeratic sand 100% DAILY ACTIVITY SUMMARY Drilled ahead to 12493' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR brumley, Sweetser DATE Dec 19, 2013 DEPTH 12532 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 12493 24 HOUR FOOTAGE 39 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 10560 1972 99.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 14.8 @ 12524 0.5 @ 12521 3.2 1.32 FT/HR SURFACE TORQUE 27716 @ 12503 34 @ 12524 25875.1 25356.53 AMPS WEIGHT ON BIT 33 @ 12523 20 @ 12514 25.7 26.81 KLBS ROTARY RPM 145 @ 12496 0 @ 12524 132.9 121.34 RPM PUMP PRESSURE 2772 @ 12494 1672 @ 12514 2636.2 2675.34 PSI DRILLING MUD REPORT DEPTH 12532 MW 12.95 VIS 47 PV 25 YP 16 FL 3.5 Gels 7/13/18 CL- 11000 FC 1/2 SOL 19.2 SD 0.25 OIL 0.5/79.5 MBL 6.0 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ 12499 0 @ 12522 1.9 TRIP GAS CUTTING GAS 0 @ 12531 0 @ 12531 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 1533 @ 12501 156 @ 12522 956.6 CONNECTION GAS HIGH ETHANE (C-2) 156 @ 12501 17 @ 12522 102.4 AVG PROPANE (C-3) 65 @ 12495 1 @ 12517 21.4 CURRENT BUTANE (C-4) 47 @ 12530 2 @ 12522 7.5 CURRENT BACKGROUND/AVG 2u PENTANE (C-5) 11 @ 12493 5 @ 12494 0.5 HYDROCARBON SHOWS See show report #10 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand 90% Tuffaceous santstone 10% PRESENT LITHOLOGY Conglomeratic sand 90% Tuffaceous santstone 10% DAILY ACTIVITY SUMMARY Drilled ahead to 12532'. Circulate bottoms up and begin POOH. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 20, 2013 DEPTH 12532 PRESENT OPERATION POOH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 10560 1972 99.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 47 PV 27 YP 17 FL 3.6 Gels 7/12/19 CL- 11000 FC 1/2 SOL 19.3 SD 0.25 OIL 0.5/79.4 MBL 6.0 pH 9.8 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue POOH through hard spots CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 21, 2013 DEPTH 12532 PRESENT OPERATION POOH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 10560 1972 99.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 49 PV 35 YP 15 FL 3.6 Gels 6/12/18 CL- 11000 FC 1/2 SOL 19.1 SD 0.15 OIL 0.5/79.6 MBL 6.0 pH 10.0 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue POOH through hard spots CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 22, 2013 DEPTH 12532 PRESENT OPERATION POOH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10463' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 10560 1972 99.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 49 PV 28 YP 19 FL 3.2 Gels 4/12/19 CL- 11000 FC 1/2 SOL 18.7 SD 0.15 OIL 0.5/80.0 MBL 6.0 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue POOH through tight spots CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 23, 2013 DEPTH 12532 PRESENT OPERATION POOH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 10560 1972 99.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 53 PV 34 YP 19 FL 3.0 Gels 6/12/18 CL- 15000 FC 1/2 SOL 18.4 SD 0.25 OIL 0.5/80.0 MBL 6.0 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue POOH through tight spots CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 24, 2013 DEPTH 12532 PRESENT OPERATION L/D BHA TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 10560 1972 99.02 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 56 PV 34 YP 14 FL 3.6 Gels 5/12/18 CL- 14000 FC 1/2 SOL 18.5 SD 0.25 OIL 0.5/80.0 MBL 6.0 pH 10.0 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue POOH to the shoe. CBU with very little cuttings returned. Pumped a dry job and tripped the rest of the way out of the hole with no problems. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sweetser DATE Dec 25, 2013 DEPTH 12532 PRESENT OPERATION RIH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 SMITH MDSi716 JH5966 3x16, 1x13 12532 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 58 PV 25 YP 20 FL 3.8 Gels 5/12/18 CL- 14000 FC 1/2 SOL 18.5 SD 0.25 OIL 0.5/80.0 MBL 6.0 pH 10.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY L/D BHA and R/U BOP test equipment and test BOP's. Service Top drive then P/U new BHA and RIH while attaching NRTR's at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Sunderland, Sweetser DATE Dec 26, 2013 DEPTH 12532 PRESENT OPERATION POOH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED RR#3 8.5 SMITH MDSi716 JH5966 3x16, 1x13 12532 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.95 VIS 48 PV 27 YP 19 FL 3.8 Gels 6/12/18 CL- 14000 FC 1/2 SOL 18.5 SD 0.25 OIL 0.5/80.0 MBL 6.0 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 27u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue TIH, replacing NRTR's. Circulate while slipping and cutting drill line. Pump dry job and begin POOH at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Sunderland, Sweetser DATE Dec 27, 2013 DEPTH 12532 PRESENT OPERATION TIH TIME 18:36:05 YESTERDAY 12532 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 SMITH MDSi716 JH5968 3x16, 1x13 12532 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 13 VIS 47 PV 20 YP 22 FL 3.0 Gels 7/9/12 CL- 14000 FC 1/2 SOL 18.5 SD 0.25 OIL 0.5/80.0 MBL 5.0 pH 9.5 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 85u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finish POOH and L/D BHA. P/U drilling BHA while servicing rig pumps. RIH to 10738' then pull back into shoe to service top drive. Resume RIH at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Sunderland, Sweetser DATE Dec 29, 2013 DEPTH 12685 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 12532 24 HOUR FOOTAGE 153 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" SMITH MDSi716 JH5968 3x16, 1x13 12532 153 14.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 23.6 @ 12673 0.9 @ 12533 11.8 5.46 FT/HR SURFACE TORQUE 28932 @ 12657 23 @ 12623 27016.4 27057.35 AMPS WEIGHT ON BIT 28 @ 12654 20 @ 12541 23.4 26.69 KLBS ROTARY RPM 137 @ 12615 0 @ 12623 130.4 131.51 RPM PUMP PRESSURE 2944 @ 12538 1 @ 12623 2728.9 2822.14 PSI DRILLING MUD REPORT DEPTH 12532 MW 13.0 VIS 47 PV 20 YP 22 FL 3.0 Gels 7/9/12 CL- 14000 FC 1/2 SOL 18.5 SD 0.25 OIL 0.5/80.0 MBL 5.0 pH 9.5 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 20 @ 12664. 1 @ 12532 10.1 TRIP GAS 125u CUTTING GAS 0 @ 12685 0 @ 12685 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 7528 @ 12535 599 @ 12532 1201.1 CONNECTION GAS HIGH ETHANE (C-2) 1084 @ 12535 79 @ 12532 195.6 AVG PROPANE (C-3) 335 @ 12545 2 @ 12603 42.4 CURRENT BUTANE (C-4) 291 @ 12535 16 @ 12545 12.8 CURRENT BACKGROUND/AVG 9u PENTANE (C-5) 0 @ 12685 0 @ 12685 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone 50% Conglomeratic Sand 40% Tuffaceous siltstone 10% PRESENT LITHOLOGY Tuffaceous Sandstone 50% Conglomeratic Sand 40% Tuffaceous siltstone 10% DAILY ACTIVITY SUMMARY Continue Washing and reaming to bottom through tight spots. Tag bottom and pump high vis sweep. Drill ahead to 12685' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $ 3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Sunderland, Sweetser DATE Dec 29, 2013 DEPTH 12910 PRESENT OPERATION RIH TIME 23:59 YESTERDAY 12685 24 HOUR FOOTAGE 225 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5'' SMITH MDSi716 JH5968 3x16, 1x13 12532 408' 26.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 66.0 @ 12860 2.0 @ 12882 24.6 18.41 FT/HR SURFACE TORQUE 33400 @ 12831 41 @ 12720 26814.7 25520.99 AMPS WEIGHT ON BIT 28 @ 12687 11 @ 12888 22.1 20.93 KLBS ROTARY RPM 149 @ 12746 0 @ 12718 129.9 133.09 RPM PUMP PRESSURE 2899 @ 12710 1419 @ 12735 2427.3 2633.83 PSI DRILLING MUD REPORT DEPTH 12910 MW 12.9 VIS 46 PV 25 YP 19 FL 3.3 Gels 8/16/19 CL- 17000 FC 1/2 SOL 18.3 SD 0.25 OIL 0.5/80.0 MBL 5.5 pH 10.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 41 @ 12708 4 @ 12714 13.6 TRIP GAS 15u CUTTING GAS 0 @ 12910 0 @ 12910 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 5416 @ 12815 574 @ 12714 1670.7 CONNECTION GAS HIGH 22u ETHANE (C-2) 520 @ 12708 64 @ 12714 198.7 AVG 7u PROPANE (C-3) 225 @ 12708 0 @ 12858 50.1 CURRENT BUTANE (C-4) 0 @ 12910 0 @ 12910 0.0 CURRENT BACKGROUND/AVG 11u PENTANE (C-5) 0 @ 12910 0 @ 12910 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous Sandstone 70% Tuffaceous siltstone 20% Carbonaceous shale 10% PRESENT LITHOLOGY Tuffaceous Sandstone 90% Tuffaceous Siltstone 10% DAILY ACTIVITY SUMMARY Drill ahead to 12910. Over pulled while back reaming before connection. Attempted to loosen pipe through alternating pumps rates, jarring and working pipe. Free'd pip and POOH 8 stands. Running back in at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Sunderland, Sweetser DATE Dec 30, 2013 DEPTH 13104 PRESENT OPERATION Short trip TIME 23:59 YESTERDAY 12910 24 HOUR FOOTAGE 194 CASING INFORMATION 13-3/8 @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" SMITH MDSi716 JH5968 3x16, 1x13 12532 600' 40.9 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 34.4 @ 13088 1.4 @ 13046 14.7 3.93 FT/HR SURFACE TORQUE 35023 @ 13076 17 @ 12911 26567.0 22689.17 AMPS WEIGHT ON BIT 22 @ 12949 8 @ 13087 18.2 17.49 KLBS ROTARY RPM 151 @ 13104 0 @ 12911 133.3 151.99 RPM PUMP PRESSURE 2651 @ 13057 1729 @ 13095 2457.3 2302.95 PSI DRILLING MUD REPORT DEPTH 13104 MW 13.4 VIS 45 PV 18 YP 23 FL 3.6 Gels 14/26/32 CL- 15000 FC 2/2 SOL 20.5 SD 0.25 OIL 1.0/77.5 MBL 6.3 pH 9.3 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 23 @ 13070 7 @ 12912 11.3 TRIP GAS 24u CUTTING GAS 0 @ 13104 0 @ 13104 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 2139 @ 13070 672 @ 13057 1070.0 CONNECTION GAS HIGH 26u ETHANE (C-2) 412 @ 13070 88 @ 13003 177.5 AVG 13u PROPANE (C-3) 222 @ 13070 43 @ 13012 79.8 CURRENT BUTANE (C-4) 147 @ 13069 8 @ 13077 3.7 CURRENT BACKGROUND/AVG 10u PENTANE (C-5) 0 @ 13104 0 @ 13104 0.0 HYDROCARBON SHOWS See Show report #11 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone 70% Tuffaceous Siltstone 20% Conglomeratic sand 10% PRESENT LITHOLOGY Tuffaceous sandstone 80% Tuffaceous Siltstone 20% DAILY ACTIVITY SUMMARY Drill ahead to 13104 and short trip out 5 stands. Running back into hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Dec 31, 2013 DEPTH 13274 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 13104 24 HOUR FOOTAGE 170 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" SMITH MDSi716 JH5968 3x16, 1x13 12532 770' 59.6 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 30.7 @ 13160 2.0 @ 13202 10.8 20.84 FT/HR SURFACE TORQUE 30167 @ 13212 2 @ 13201 27144.9 27813.27 AMPS WEIGHT ON BIT 27 @ 13190 17 @ 13274 22.3 17.48 KLBS ROTARY RPM 151 @ 13104 121 @ 13149 133.2 137.40 RPM PUMP PRESSURE 2819 @ 13251 1380 @ 13269 2514.6 1846.33 PSI DRILLING MUD REPORT DEPTH 13275 MW 13.65 VIS 45 PV 18 YP 25 FL 4.4 Gels 16/27/34 CL- 14000 FC 2/2 SOL 21.3 SD 0.25 OIL 1.5/76.2 MBL 9.0 pH 9.1 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 103 @ 13160 7 @ 13108 22.2 TRIP GAS 13u CUTTING GAS 0 @ 13274 0 @ 13274 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 11601 @ 13176 807 @ 13108 2312.3 CONNECTION GAS HIGH 32u ETHANE (C-2) 2020 @ 13160 118 @ 13108 416.9 AVG PROPANE (C-3) 1322 @ 13160 50 @ 13108 273.8 CURRENT 3u BUTANE (C-4) 746 @ 13181 1 @ 13117 138.9 CURRENT BACKGROUND/AVG 20u PENTANE (C-5) 400 @ 13181 3 @ 13212 50.4 HYDROCARBON SHOWS See show report #12 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tuffaceous sandstone 30% Conglomeratic sand 30% sand 20% tuffaceous siltstone 10% PRESENT LITHOLOGY Conglomeratic sand 30% sand 30% Tuffaceous sandstone 20% tuffaceous siltstone 10% DAILY ACTIVITY SUMMARY Wash back to bottom and drill. Drilling ahead at 13274' at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Jan 01, 2014 DEPTH 13531 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 13274 24 HOUR FOOTAGE 257 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" SMTH MDSi716 JH5968 3x16,1x13 12532 1027 79.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 46.5 @ 13484 1.9 @ 13339 14.9 20.12 FT/HR SURFACE TORQUE 31862 @ 13414 5 @ 13394 27883.6 28590.83 AMPS WEIGHT ON BIT 28 @ 13513 8 @ 13482 23.9 27.03 KLBS ROTARY RPM 147 @ 13354 0 @ 13486 131.6 134.50 RPM PUMP PRESSURE 2391 @ 13491 1622 @ 13344 2087.4 2249.41 PSI DRILLING MUD REPORT DEPTH 13494 MW 13.65 VIS 45 PV 17 YP 21 FL 3.9 Gels 13/24/32 CL- 15000 FC 2/3 SOL 22.1 SD 0.25 OIL 1.0/75.9 MBL 7.5 pH 9.7 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 @ 13449 6 @ 13300 21.4 TRIP GAS CUTTING GAS 0 @ 13531 0 @ 13531 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4874 @ 13486 578 @ 13300 2127.7 CONNECTION GAS HIGH 15u ETHANE (C-2) 821 @ 13486 134 @ 13300 406.9 AVG 10u PROPANE (C-3) 673 @ 13449 78 @ 13364 303.3 CURRENT BUTANE (C-4) 449 @ 13486 49 @ 13364 185.2 CURRENT BACKGROUND/AVG 12 PENTANE (C-5) 268 @ 13292 3 @ 13326 72.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand 90% Tuffaceous sandstone 10% PRESENT LITHOLOGY Conglomeratic sand 80% Tuffaceous sandstone 10% Carbonaceous Shale 10% DAILY ACTIVITY SUMMARY Continue drilling ahead to 13531 at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,575 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Jan 02, 2014 DEPTH 13670 PRESENT OPERATION MAD pass / working tight spot TIME 23:59 YESTERDAY 13531 24 HOUR FOOTAGE 139 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" SMITH MDSi716 JH5968 3x16, 1x13 12532' 1166' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 36.5 @ 13617 3.2 @ 13663 16.7 12.97 FT/HR SURFACE TORQUE 31667 @ 13615 27100 @ 13581 28733.9 28771.16 AMPS WEIGHT ON BIT 29 @ 13593 15 @ 13616 24.9 22.69 KLBS ROTARY RPM 141 @ 13663 124 @ 13637 135.9 137.42 RPM PUMP PRESSURE 2342 @ 13547 2075 @ 13631 2283.6 2227.75 PSI DRILLING MUD REPORT DEPTH MW 13.65 VIS 45 PV 18 YP 22 FL 3.0 Gels 12/24/26 CL- 15000 FC 2/3 SOL 22.8 SD 0.25 OIL 1.5/74.7 MBL 6.5 pH 9.1 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 39 @ 13612 5 @ 13669 19.5 TRIP GAS CUTTING GAS 0 @ 13670 0 @ 13670 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4703 @ 13618 910 @ 13662 2076.5 CONNECTION GAS HIGH ETHANE (C-2) 1014 @ 13618 202 @ 13573 419.8 AVG PROPANE (C-3) 884 @ 13618 121 @ 13638 339.0 CURRENT BUTANE (C-4) 542 @ 13618 56 @ 13667 201.3 CURRENT BACKGROUND/AVG 6u PENTANE (C-5) 358 @ 13618 38 @ 13584 144.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Conglomeratic sand 70% Tuffaceous siltstone 20% coal 10% PRESENT LITHOLOGY Conglomeratic sand 90% Tuffaceous siltstone 10% DAILY ACTIVITY SUMMARY Drilled ahead to TD at 13670'. CBU and begin POOH through tight spot at 13180'. Begin pumping out to 12578' encountered another tight spot. Setting off jars and working hole at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Jan 03, 2014 DEPTH 13670 PRESENT OPERATION MAD pass, working tight spots TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 SMITH MDSi716 JH5968 3x16, 1x13 12532' 1165' 88.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 13.8 VIS 42 PV 17 YP 23 FL 3.7 Gels 12/21/24 CL- 15000 FC 2/2 SOL 23.5 SD 0.25 OIL 1.5/74.0 MBL 5.5 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Continue MAD passing/POOH through tight spots. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $ 3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Jan 04, 2014 DEPTH 13670 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 SMITH MDSi716 JH5968 3x16, 1x13 12532' 1165' 88.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 45 PV 20 YP 21 FL 3.0 Gels 9/18/21 CL- 14000 FC 2/3 SOL 23.8 SD 0.25 OIL 1.5/73.8 MBL 5.8 pH 9.4 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 30u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Continue POOH through tight spots. CANRIG PERSONNEL ON BOARD 4 DAILY COST DML $ 3,043 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Jan 05, 2014 DEPTH 13670 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 SMITH MDSi716 JH5968 3x16, 1x13 12532' 1165' 88.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 46 PV 21 YP 17 FL 3.7 Gels 9/17/20 CL- 15000 FC 1/2 SOL 23.4 SD 0.25 OIL 0.8/74.8 MBL 5.5 pH 10.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 18u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Continue POOH through tight spots. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Hauck, Sunderland DATE Jan 06, 2014 DEPTH 13670 PRESENT OPERATION Replacing WWT torque reducers TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5 SMITH MDSi716 JH5968 3x16, 1x13 12532' 1165' 88.5 5-8-BT-A-X-8-LT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 48 PV 15 YP 15 FL 4.4 Gels 9/15/19 CL- 15000 FC 1/2 SOL 23.7 SD 0.20 OIL 0.8/74.5 MBL 5.3 pH 9.8 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Finished POOH and discovered clamp on stabilizer was left in hole. Running in hole to replace WWT torque reducers at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 07, 2014 DEPTH 13670 PRESENT OPERATION R/U to Test BOP's TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 45 PV 14 YP 14 FL 5.0 Gels 9/16/19 CL- 14000 FC 1/3 SOL 23.1 SD 0.25 OIL 0.8/75.2 MBL 5.0 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Finished replacing worn NRP's and racked back DP. R/U wirline and ran caliper log. Rigging up to test BOP's at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 08, 2014 DEPTH 13670 PRESENT OPERATION R/U casing equipment TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 46 PV 17 YP 15 FL 4.5 Gels 7/17/21 CL- 14000 FC 2/3 SOL 23.1 SD 0.20 OIL 0.8/75.2 MBL 5.3 pH 9.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Finished testing BOP's and Rig down testing equipment. R/U Weatherford casing equipment and prep to RIH with 7" liner. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 09, 2014 DEPTH 13670 PRESENT OPERATION RIH w/7" liner TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.9 VIS 49 PV 17 YP 13 FL 6.4 Gels 6/10/19 CL- 14000 FC 2/3 SOL 23.3 SD 0.15 OIL 0.5/75.2 MBL 6.5 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 29u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Running in hole with 7" liner. at 10,170' at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 10, 2014 DEPTH 13670 PRESENT OPERATION POOH TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 73 PV 32 YP 34 FL 3.9 Gels 11/18/22 CL- 16000 FC 2/3 SOL 22.9 SD 0.15 OIL 1.0/75.0 MBL 5.8 pH 10.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 50u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Continue RIH with 7" liner. CBU before getting into open hole at 10620'. Work through tight hole at 10280', 11636', 12584' and 12896'. Liner was detained at 12897, lost circulationa dn pipe rotation. Attempted to pull up to 660K with no luck. Decision was made to set hanger and TOOH. While pressuring up to set hanger @ 1950 the psi broke over and mud was injected away at 4-5 bbls/min. Released from hanger and established circulation. no losses following release. POOH at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 11, 2014 DEPTH 13670 PRESENT OPERATION Testing BOP's TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 92 PV 24 YP 29 FL 4.4 Gels 10/22/25 CL- 16000 FC 2/3 SOL 22.9 SD 0.10 OIL 0.5/75.5 MBL 6.0 pH 10.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Finished POOH and L/D 5.5" DP and HWDP. Changed out upper rams and testing BOP's at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 12, 2014 DEPTH 13670 PRESENT OPERATION Rig service TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 72 PV 21 YP 25 FL 4.6 Gels 9/20/24 CL- 15000 FC 2/3 SOL 23.2 SD 0.15 OIL 0.5/75.3 MBL 6.3 pH 10.4 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Finish testing BOP's and begin P/U 4" DP. Shut down due to turbine failure. Troubleshooting at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Sunderland DATE Jan 13, 2014 DEPTH 13670 PRESENT OPERATION Rig service TIME 23:59 YESTERDAY 13670 24 HOUR FOOTAGE 0 CASING INFORMATION 13-3/8" @ 3533' 9-5/8" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670'pit 4 MW 13.9 VIS 62 PV 24 YP 23 FL 6.7 Gels 7/16/19 CL- 15000 FC 2/3 SOL 23.7 SD 0.15 OIL 0.5/74.8 MBL 5.0 pH 8.5 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY no new footage drilled DAILY ACTIVITY SUMMARY Continue waiting on parts for turbine while servicing the rig CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $ 2,239 RW $1,795 REPORT BY Dubowski Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 14, 2014 DEPTH 13670' PRESENT OPERATION Rig Service TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 57` PV 19 YP 17 FL 7.0 Gels 5/12/18 CL- 14,000 FC 2/2 SOL 22.8 SD 0.15 OIL 0.5/75.7 MBL 6.0 pH 9.5 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Waiting on parts for turbine while servicing the rig. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2,239.00 RW $1,795.00 REPORT BY Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 15, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 60 PV 29 YP 20 FL 4.4 Gels 6/12/18 CL- 15,000 FC 1/2 SOL 22.7 SD 0.15 OIL 0.5/75.8 MBL 6.0 pH 10.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 15u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/2u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Service rig, change out circuit breaker on generator #2, circulate and condition mud, trip in hole from 3878' to 10239', circulate and condition mud, trip in hole to 12,738', set cement retainer at 12735', circulate, start pulling out of hole to 7,505' at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2,239.00 RW $1,795.00 REPORT BY Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 16, 2014 DEPTH 13670' PRESENT OPERATION Tripping In Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 55 PV 21 YP 14 FL 7.8 Gels 4/8/12 CL- 14,000 FC 1/2 SOL 23.1 SD 0.15 OIL 0.5/75.4 MBL 6.0 pH 8.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole from 7,505', log cased hole, perferate casing, pick up BHA, make up baker cement retainer, trip in hole with cement retainer to 10051' at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2,239.00 RW $1,795.00 REPORT BY Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 17, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 58 PV 21 YP 17 FL 7.2 Gels 5/12/18 CL- 14,000 FC 1/2 SOL 23.1 SD 0.15 OIL 0.5/75.4 MBL 6.0 pH 9.5 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 37u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/3u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Trip in hole with cement retainer from 10051’ to set retainer at 12398’, circulate and condition mud, rig up cement line, pressure test cement lines, pump cement and spacer, start pulling out of hole to 11871' at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2,239.00 RW $1,795.00 REPORT BY Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 18, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 50 PV 18 YP 15 FL 7.8 Gels 5/10/15 CL- 14,000 FC 1/2 SOL 23.1 SD 0.15 OIL 0.5/75.4 MBL 6.0 pH 10.5 Ca+ 140 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole and lay down Baker tools, service and clean rig, pick up BHA/chang out elevators, trip in hole to 9368’, wash to tag cement @ 9411’, circulate and condition mud, pull out of hole to 539’ at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2,239.00 RW $1,795.00 REPORT BY Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 19, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 62 PV 26 YP 22 FL 6.5 Gels 7/11/18 CL- 14,000 FC 1/2 SOL 22.5 SD 0.15 OIL 0.5/76.0 MBL 6.0 pH 10.1 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole and lay down Baker tools, change elevators, pick up packer and trip in hole to 6321’, cut and slip drill line, service rig, trip in hole to 9391’, circulate and condition mud, pressure test cement lines, seat ball in packer, release from packer and pull out of hole to 6037’ at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2,239.00 RW $1,795.00 REPORT BY Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 20, 2014 DEPTH 13670' PRESENT OPERATION Testing BOP's TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 57 PV 22 YP 17 FL 6.8 Gels 6/11/18 CL- 14,000 FC 1/2 SOL 22.8 SD 0.15 OIL 0.5/76.0 MBL 6.0 pH 10.0 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole from 6037’, lay down BHA and packer, run wireline logs, rig up and test casing, test BOP’s CANRIG PERSONNEL ON BOARD 2 DAILY COST 2 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 21, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 56 PV 22 YP 19 FL 7.5 Gels 5/10/16 CL- 14,000 FC 1/2 SOL 21.3 SD 0.15 OIL 0.2/77.5 MBL 6.0 pH 9.0 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Test BOP’s, pick up BHA, trip in hole to 9360’, wash down and tag cement at 9409’, circulate and condition mud, pump slug, pull out of hole to 3205’ at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 22, 2014 DEPTH 13670' PRESENT OPERATION Laying Down BHA TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 55 PV 23 YP 19 FL 6.5 Gels 6/9/16 CL- 14,000 FC 1/2 SOL 21.3 SD 0.15 OIL 0.2/77.6 MBL 6.0 pH 9.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole, lay down BHA, pick up mill bit, trip in hole to 9368’, wash to tag cement at 9408’, mill and dress liner to 9411’, pull out of hole and lay down BHA. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 23, 2014 DEPTH 13670' PRESENT OPERATION Reaming And Washing TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 53 PV 23 YP 18 FL 6.7 Gels 5/8/12 CL- 15,000 FC 1/2 SOL 21.3 SD 0.15 OIL 0.2/77.5 MBL 6.0 pH 9.6 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pick up BHA, trip in hole with mill assembly, tag packer at 9403’, mill and dress packer from 9403’ to 9405’, wash down to 9430’ at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 24, 2014 DEPTH 13670' PRESENT OPERATION Drilling Cement TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 54 PV 23 YP 18 FL 6.8 Gels 5/8/12 CL- 15,000 FC 1/2 SOL 21.2 SD 0.15 OIL 0.2/77.6 MBL 6.0 pH 9.4 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pick up BHA, trip in hole with mill assembly, tag packer at 9403’, mill and dress packer from 9403’ to 9405’, wash down to 9430’ at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 25, 2014 DEPTH 13670' PRESENT OPERATION Drilling Cement TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 54 PV 25 YP 19 FL 6.2 Gels 5/11/19 CL- 14,000 FC 1/2 SOL 21.4 SD 0.15 OIL 0.2/77.5 MBL 6.0 pH 9.5 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1u/1u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Drilling cement from 12442’ to 12456’, washing and reaming from 12456’ to 12779’, drilling cement from 12779’ to 12914’, working stuck pipe at 12914’, jar pipe loose, circulate and condition mud and redrill shoe from 12910’ to 12911’ at report time. Max gas last 24 hours 4 units. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 26, 2014 DEPTH 13670' PRESENT OPERATION Laying Down BHA TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 64 PV 29 YP 30 FL 5.0 Gels 7/13/19 CL- 14,000 FC 1/2 SOL 21.4 SD 0.15 OIL 0.2/77.5 MBL 6.0 pH 10.0 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1u/1u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Drilling cement from 12911’ to 12914’,back ream to 12845’, wash and ream from 12845’ to 12921’, back ream to 12900’, ream to 12935’, packed off , back ream circulate and condition mud, pull out of hole, lay down bit and stabilizers at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 27, 2014 DEPTH 13670' PRESENT OPERATION Washing and Reaming TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.8 VIS 58 PV 27 YP 27 FL 5.0 Gels 7/12/18 CL- 15,000 FC 1/2 SOL 21.3 SD 0.15 OIL 0.2/77.5 MBL 5.0 pH 9.7 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/1u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pick up BHA, trip in hole with 6” bit to 10225’, cut and slip drill line, trip in hole from 10225’ to 12900’, wash and ream from 12900’ to 12931’. Max gas last 24 hours 8 units. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 28, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 63 PV 31 YP 29 FL 3.6 Gels 7/15/18 CL- 13,000 FC 1/2 SOL 21.3 SD 0.20 OIL 0.3/77.5 MBL 5.0 pH 9.6 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/3u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Washing and reaming from 12931’ to 12942’, packed off, work back into shoe at 12908’, circulate and condition mud, washing and reaming from 12908’ to 12980’, packing off at 12980’, working tight spot 12980’ to 12905’, pulling out of hole from 12905’ to 11616’ at report time. Max gas last 24 hours 23 units reaming @ 12970’. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 29, 2014 DEPTH 13670' PRESENT OPERATION Pulling Out of Hole TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 63 PV 31 YP 29 FL 3.6 Gels 7/15/18 CL- 13,000 FC 1/2 SOL 21.3 SD 0.20 OIL 0.3/77.5 MBL 5.0 pH 9.6 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/1u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole and lay down BHA, pick up new BHA, trip in hole to 12866’ scraper @ 12852’, circulate and condition mud, pull out of hole from 12866’ to 9280’ at report time. Max gas last 24 hours 2 units. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn Hilcorp Alaska, LLC Granite Point Field DAILY WELLSITE REPORT Anna 17A REPORT FOR Brumley, Suderland DATE Jan 30, 2014 DEPTH 13670' PRESENT OPERATION Pressure Testing TIME 23:59 YESTERDAY 13670' 24 HOUR FOOTAGE 0' CASING INFORMATION 13.375" @ 3533' 9.625" @ 10470' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13670' MW 13.85 VIS 56 PV 28 YP 24 FL 5.1 Gels 6/11/14 CL- 13,000 FC 1/2 SOL 21.3 SD 0.10 OIL 0.3/77.5 MBL 5.0 pH 9.2 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT N/A BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0u/0u PENTANE (C-5) @ @ HYDROCARBON SHOWS No new hole drilled last 24 hours. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new hole drilled last 24 hours. DAILY ACTIVITY SUMMARY Pull out of hole and lay down BHA, Pick up plug tools, trip in hole to 12850’, circulate and condition mud, pressure up to 2000 psi for 2 min., pick up to 1242’ and pressure up to 3000 psi, attempt to reverse circulate to 2000 psi, test casing @ 1000 psi bled to 830 psi and held. CANRIG PERSONNEL ON BOARD 2 DAILY COST DML $2239.00 RW $1795.00 REPORT BY M. Strawn