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Home My WebLink About214-054CAUTION: 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:Rixse, Melvin G (OGC) To:Ryan Rupert Cc:Sara Hannegan; Patrick Stewart - (C); Mike Grubb - (C); Darci Horner; Joshua Zuber; Dewhurst, Andrew D (OGC); DOA AOGCC Prudhoe Bay Subject:20251024 1500 APPROVAL UPPER COMPLETION CHANGE PTD 215-054 ODSN-22 path forward Date:Friday, October 24, 2025 3:03:30 PM Attachments:ODSN-22 Proposed Schematic 10-24-2025.pdf image001.png Ryan, Hilcorp is approved to change upper completion on well PTD 215-054 Sundry 325-546 ODSN-22 as described in the attached schematic and procedure below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inspectors, Andy Dewhurst From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Friday, October 24, 2025 2:49 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Patrick Stewart - (C) <Patrick.Stewart@hilcorp.com>; Mike Grubb - (C) <Mike.Grubb@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Joshua Zuber <Joshua.Zuber@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: RE: ODSN-22 path forward Mel- Per our conversation, Hilcorp proposes the following modified completion (rough schematic attached). Our high-level path forward is also outlined below: Modified completion Base permafrost at 1975’ MD (-1611’ TVDss) Downsize TRSSSV to 2-7/8” and set at 2200’ MD (-1710’ TVDss) Move packer to 1400’ MD (-1302’ TVDss) to avoid high DLS below Packer will have GLM’s close above and below. Normal operating conditions will have these dummied Modified path forward POOH to packer Hang off and BOPE test Run new modified completion per above Same final steps and testing requirements per sundry Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 907-301-1736 (Cell) 907-777-8503 (Office) From: Ryan Rupert Sent: Friday, October 24, 2025 10:32 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Sara Hannegan <shannegan@hilcorp.com>; Patrick Stewart - (C) <Patrick.Stewart@hilcorp.com>; Mike Grubb - (C) <Mike.Grubb@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Joshua Zuber <Joshua.Zuber@hilcorp.com> Subject: ODSN-22 path forward Mel- Per our conversation, please see below for events to date for in progress ODSN-22 HWO. Given the mechanical challenges with getting the completion to planned depth, Hilcorp would like to request a waiver to AOGCC regulation 20 AAC 25.265.G.2, and plan to set the SSSV above the base permafrost. Hilcorp believes due to the observed static temperature gradient, and the relatively hot anticipated production stream, that setting the SSSV above the base permafrost will still allow for robust well control, and functioning SVS. Planned completion Top liner: 14,449’ MD (-5796’ ssTVD) End of ESP completion / screens: 15,200’ MD (-5977 ssTVD) Packer: 3775’ MD (-2243’ ssTVD) Biggest and longest completion component at 5.99” OD x 11’ long Running inside 6.276” ID casing (6.151” drift) TRSSSV: 3600’ MD (-2189’ ssTVD) Base permafrost: 1975’ MD (-1611’ ssTVD) No shallow logs in ODSN-22 We’re pulling together logs/map currently and can send those over shortly Events thus far Ran completion to 13,246’ MD (-5364’ ssTVD) Placed packer at 1765’ MD (-1499’ ssTVD) Placed SSSV at 1590’ MD (-1384’ ssTVD) Unable to move down or up at 80% max pull Pumped 5 lube pills over previous day Unable to go down, but have successfully pulled completion ~325’ uphole Stopped there, and standing by for path forward See below for shallow deviation survey Challenging DLS from 1700-2100’ MD Proposal Plan to set completion where it’s at currently Attempt to work back to previous depths if practical, but don’t want to unnecessarily stress the packer any more. This would put SSSV at 1590’ MD (-1384’ ssTVD) This places SSSV within 230’ ssTVD of base permafrost Reservoir pressure in ODSN-22 is no greater than 2050psi at -6350’ TVDss (<6.3ppg) See attached for offset static temp log from ODSK-33 (shut in for 10+ years) Proposed set depth will be >32F Ryan Rupert WNS Ops Engineer (#4508) ODS & OPP Drill Sites 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 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 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. Oooguruk Field Last Completed: 6/2/2015 PTD: 215-054 API #: 50-703-20708-00-00 Casing Hole MD 16”158' 16" A 3 9-5/8"11,720' B 4-1/2"22,208' 2 C Size ID Top Btm Btm TVD D 16”N/A Surface 158' 158' 11-3/4" 10.772" Surface 6,548' 3,211' E 9-5/8"8.835" 6,391' 11,717' 4,915' 7"6.276" Surface 15,699' 6,077' 4-1/2”3.958" 15,430' 22,205' 6,197' 11-3/4"3-1/2"2.992" Surface 1,300' 1,224' 2-7/8"2.441" 1,300' 2,300' 1,805' 3-1/2"2.992" 2,300' 14,100' 5,704' 2-7/8"2.441" 14,100' 14,665' 5,887' No. MD(ft) TVD(ft) Inc ID 9-5/8"A 1,300 1,224' 36 B 1,400 1,303' 40 F C 1,480 1,362' 43 D 2,200 1,766' 66 1 E 2,300 1,805' 69 F 14,100 5,704' 70 G 14,630 5,876' 72 G H 14,665 5,887' 72 I 14,775 5,921' 72 J 14,780 5,923' 71 H K 15,449 6,055' 85 5.25" St. Size MD (ft)TVD (ft)Inc GLM Type Valve Latch Port 3 2-7/8" 1,360 1,272 38 TBD Shear TBD NA I 2 2-7/8" 1,440 1,332 42 TBD Dummy TBD NA 1 2-7/8" 14,150 5,720 71 TBD OV TBD TBD J 3-1/2" x 2-7/8" XO ZXP Liner Top Packer, Flex-Lock Liner Hanger and Tie-Back Extension ESP Pump Assembly, Discharge gauge with shroud Bottom of ESP Assembly, Centralizer 2-7/8" "XN" Nipple Screens below shroud, 400' long, bottom @ ~ 15,180' ODSN-22 Proposed Schematic Nuiqsut Producer 11-3/4"6,558'14-1/2" hole, 648 bbls (931sx) 11.3 ppg Permafrost 'L' plus 121 bbls (580 sx) of 15.8 ppg tail. Returns to surface. Driven in 24" hole Cement Details TUBING DETAIL Description 7" x 2-7/8" ESP Packer with Packer Vent Valve 2-7/8" TRSSSV with control line to surface 2-7/8" x 3-1/2" XO Tubing 9.2#, L-80, EUE UPPER COMPLETION EQUIPMENT 2-7/8" "X" Nipple 3-1/2" x 2-7/8" XO Tubing 6.4#, L-80, W533 Tubing 9.2#, L-80, EUE Tubing 6.4#, L-80, W533 Wt/ Grade/ ConnType 12-1/4" hole, 42 bbls (200 sx) 15.8 ppg Premium 'G'. TOC ? CEMENT DETAIL 15,726' CASING DETAIL 7" 8-3/4" hole, 1st stage: 78 bbls (365 sx) 15.7 ppg Premium 'G'. Experienced losses while pumping. TOC @ 14,512' MD from 5/14/15 BAT sonic log. 2nd stage: 53 bbls (255 sx) 15.8 ppg Premium 'G'. Full returns. TOC logged up to 11,700' MD. 6-1/8" Open Hole, Uncemented Ball Actuated Sleeves and Swell Packers Surface Intermediate 1 Intermediate 2 Production Liner 100#, X-65 60#, L-80, BTC-M 40#, L-80, HYD 521 26#, L-80, HYD 563 12.6#, C-110, Hyd 521 Conductor GAS LIFT MANDRELS Well Fractured 2/1/2016 TBD TBD Date TBD Date Complete Jun 2015 Event Drilled & Completed K 4-1/2" liner from 15,430' MD (6,054' TVD) to 22,205' MD (6,197' TVD) Resman Internally Vented Carrier (x4) 7" Swell Packers (x13) Ball Actuated Sleeves (x 11) One Ported Pup @ 22,147' MD (6,195' TVD) 70 degree inclination @ X SSSV XN ES Cementer Base of Torok 0000 0 0 ODSN-22 Proposed Schematic 10-24-2025 Last edited by: DH 10/24/2025 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,525 feet N/A feet true vertical 10,903 feet Unknown feet Effective Depth measured 11,276 feet 9,007 feet true vertical 10,276 feet 9,007 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 9,030' MD 9,030' TVD Olgoonik Packers and SSSV (type, measured and true vertical depth)AS1-1 Mech; N/A 9,007' MD 9,007' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: 7,910psi Burst 8,810psi 28' 2,981'2,730psi Collapse 1,130psi 6,590psi 6,710psi Casing Structural 20" 13-3/8" Length 28' 2,981' 9,380' Conductor Surface Intermediate Production Authorized Signature with date: Authorized Name: 975 Casing Pressure Liner 2,367' 1,665 10,815' 37 Representative Daily Average Production or Injection Data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-339 405 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 33 Gas-Mcf 980 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214--054 50-133-10170-01-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 400923 Soldotna Creek Unit (SCU) 44B-33 N/A FEDA028990 Plugs Junk measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Hemlock OilN/A measured TVD Tubing PressureOil-Bbl measured true vertical Packer 6-5/8" 4" 9,380'9,380' WINJ WAG 1,658 Water-Bbl MD 28' 2,981' 11,403' 790 t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:27 am, Sep 28, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.25 16:45:18 -08'00' Taylor Wellman no change to wellbore (gls 10/20/20) RBDMS HEW 10/26/2020 gls 1/20/20 DSR-9/28/2020 SFD 9/29/2020 Rig Start Date End Date E-Line 8/31/20 8/31/20 08/31/2020 - Monday Sign in. Mobe to location. PTW and JSA. Spot and rig up equipment. PT lubricator to 250 psi low and 3,500 psi high. RIH w/ 2-3/8" x 25' HC Razor, 6 spf, 60 degree phase and tie into OHL Tools sat down at 8,450'. Tried to pick up but was stuck. Called town and discussed. Started at safe pullout at 1,800', would add 100# each time we worked tools. Tools came free at 2,800 #. POOH Got all tools back ok. Rig down off well. Will have slickline out in the morning at 7 am. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SCU 44B-33 50-133-10170-01 214-054 Daily Operations: Did not perf well. gls Updated by DMA 04-18-18 SCU 44B-33 SCHEMATIC Swanson River Unit Well SCU 44B-33 Completion Ran 5/26/14 Updated 4/27/16 TD = 11,525’ PBTD = 11,276’ MAX HOLE ANGLE = 55° @ 10,554’ RKB: 151’ / GL: 136’ AMSL KB – THF: 19.5’ H-7 DV @ 8,514 TOL 9,036’ CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor - - - Surf 28’ - unknown Surf. 13-д” Surf Csg 54.5 J-55 12.615” Surf 1,477’ 18- з” 1200 sx Surf. 13-д” DV Collar 1,477’ 1,479’ 13-д” 54.5 J-55 12.615” 1,479’ 2,981’ 600 sx 1,479’ 6-з” Prod Csg 28 P-110 5.791” Surf 92’ 10- з” 600 sx 6,700’ (Est) 6-з” 28 N-80 5.791” 92’ 6,671’ 6-з” 24 P-110 5.921” 6,671’ 8,514’ 6-з” DV Collar 8,514’ 8,516’ 6-з” 24 P-110 5.921” 8,516’ 9,380’ 600 sx 9,100’ (Est) 4” Liner 9.5 L-80 3.468” 9,036’ 11,403’ 5-з” 242 sx 9,544’ CBL TUBING DETAIL Cplg OD 3 ½ ”, EUE 8RD 9.3 L-80 2.992” 0’ 9,030’ 4.500” 20” 28’ 13-3/8” 2,017’ 6-5/8” 9,380’ 4” 11,403’ CBL EST 9,100’ CBL EST 6,700’ 1 5 6 7 4 8 9 X 2 3 JEWELRY DETAIL No. Depth ID OD Item 1 20’ 2.992” - Tubing Hanger, 3-1/2” 8RD Box x 3-1/2” 8RD Box 2 21’ 2.992” 3.500” Pups, 3-1/2” 8RD 3 4,108’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #3 (Live Valve) 4 6,993’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #2 (Live Valve) 5 8,500’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD Extra (Dummy) 6 8,953’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #1 (Orifice) 7 9,007’ 3.000” 5.500” Olgoonik AS1-X Mechanical Packer (24#-32#) 8 9,020’ 2.813” 4.438” X-Nipple 9 9,030’ 2.992” 4.438” WL Entry Guide 10 ? - - Fish (J-lugs and packer rubbers from 6-5/8” 24# AS1-X) LIH 5/23/14 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments H-1 10,591’ 10,623’ 10,294’ 10,312’ 6 32 60 11/16/17 Open H-2 10,623’ 10,644’ 10,312’ 10,325’ 6 21 60 11/16/17 Open H-3 10,660’ 10,685’ 10,334’ 10,349’ 6 25 60 11/08/17 Open H-4 10,700’ 10,715’ 10,358’ 10,366’ 6 15 60 3/29/18 Open H-5 10,754’ 10,779’ 10,389’ 10,404’ 6 25 60 11/08/17 Open H-5 10,798’ 10,804’ 10,415’ 10,419’ 6 6 60 11/08/17 Open H-5 10,831’ 10,851’ 10,435’ 10,447’ 6 19 60 11/08/17 Open H-5 10,910’ 10,950’ 10,484’ 10,510’ 6 40 60 05/31/14 2.5” Connex H-7 11,050’ 11,070’ 10,575’ 10,588’ 6 20 60 05/31/14 2.5” Connex Short Marker Joints @ 10,589'-10,599' MD @ 10,841'-10,851' MD @ 10,973'-10,992' MD CBL TOC 9,544’ Mrk Jt DV @ 1,477 H-5 Mrk Jt Mrk Jt Openhole 11,525’ 10 H-1 H-3 H-2 H-4 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,525'Unknown Casing Collapse Structural Conductor Surface 1,130psi Intermediate Production 6,710psi Liner 6,590psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8503 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng todd.sidoti@hilcorp.com 10,903'11,276'10,276'~2824 psi N/A Olgoonik AS1-X Mechanical; N/A 9,007' MD, 9,007' TVD; N/A Perforation Depth TVD (ft): Tubing Size: COMMISSION USE ONLY Authorized Name: 7,910psi Tubing Grade:Tubing MD (ft): See Attached Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028990 214-054 50-133-10170-01-00 Soldotna Creek Unit (SCU) 44B-33 Swanson River Field / Hemlock Oil Length Size CO 123B Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY 9.3# / L-80 TVD Burst 9,030' 8,810psi MD 2,730psi 28' 2,981' 28' 2,981' 9,380'6-5/8" 20" 13-3/8" 28' 2,981' 9,380' Perforation Depth MD (ft): See Attached Schematic 9,380' 4" Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: August 27, 2020 11,403'2,367' 3-1/2" 10,815' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 11:46 am, Aug 14, 2020 320-339 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.08.14 09:35:25 -08'00' Taylor Wellman DSR-8/17/2020SFD 8/14/2020 OIL Perforate gls 8/24/20 10-404 dts 8/24/2020 8/24/2020 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.24 14:25:33 -08'00' RBDMS HEW 8/26/2020 Well Prognosis Well: SCU 44B-33 Date: 8/13/2020 Well Name: SCU 44B-33 API Number: 50-133-10170-01-00 Current Status: GL Oil Producer Leg: N/A Estimated Start Date: 8/15/2020 Rig: Rigless Reg. Approval Req’d: 10-403 Sundry Number: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-054 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (907) 867-0665 (C) AFE Number Current Bottom Hole Pressure: ~ 3,300 psi @ 10,856’ TVD (Using Hemlock gradient 0.303 psi/ft) Maximum Expected BHP: ~3,910 psi @ 10,856’ TVD (Based on 1974 pressure survey) Max. Potential Surface Pressure: ~2,824 psi 0.1 psi/ft gas to surface Brief Well Summary: In 2014, SCU 44B-33 was sidetracked from SCU 14-34, a Hemlock-only oil producer originally drilled in 1960. After various workovers for Hemlock zonal isolation, SCU 14-34 eventually grew uncompetitive and its wellbore was used to develop Hemlock oil in benches H1 – H7 to the west via SCU 44B-33. The Saxon #169 rig finished drilling the sidetrack on 5/31/2014. For the first 3.5 years, SCU 44B-33 produced exclusively from the lower H5 and H7 benches. Throughout November 2017, upper H5, H1, H2, and H3 sands were added. Shortly thereafter, in March 2018, the H4 bench was shot. At the end of 2018, gas lift was turned off because the well was responding nicely to gas injection from SCU 344-33i, reaching 145 BOPD at the peak of the gas flood. Once the gas injector was turned off in late-May 2020, SCU 44B-33 returned to its previously-low rates (~35 BOPD). There are no plans to restore the gas flood in this area so it is now worthwhile to progress end-of-life Hemlock perforations. Objective: Boost oil production in a formerly-gas flooded well by adding end-of-life perforations in H7L, H9, and H12. Additionally, the H12 bench is poorly developed in this area and has potential to access new oil reserves. At the end of this job, SCU 44B-33 will be open throughout the Hemlock (H1 – H5, H7, H7L, H9, and H12). E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3500 psi high. 2. These perforations are all in oil bearing zones, we will not need N2. 3. Perforate with 2-3/8” 6 SPF 60 deg phased perf guns with the well flowing FOC. a. Use GR/CCL to correlate to Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer (Todd Sidoti), Reservoir Engineer (Meredyth Richards) and Geologist (Ben Siks) for confirmation. b. We will be perforating the H12 and letting the well flow until the following day. c. On day 2 we will shoot the H9, let the well flow for a couple hours and then shoot the H7L. 4. POOH. RD e-line. 5. Turn well over to production. There are no plans to restore the gas flood in this area so it is now worthwhile to progress end-of-life Hemlock perforations. Well Prognosis Well: SCU 44B-33 Date: 8/13/2020 Proposed Perforation Intervals 1. Sand MD Top MD Bottom Total Footage (MD) TVD Top TVD Bottom H7L ±11,000' ±11,010' 10' ±10,542' ±10,552' H9 ±11,100' ±11,120' 20' ±10,614' ±10,634' H12 ±11,425' ±11,450' 25' ±10,831' ±10,856' H12 ±11,425' ±11,450' 25' ±10,831'±10,856' H7L ±11,000' ±11,010' 10' ±10,542'±10,552' H9 ±11,100' ±11,120' 20' ±10,614'±10,634' Updated by DMA 04-18-18 SCU 44B-33 SCHEMATIC Swanson River Unit Well SCU 44B-33 Completion Ran 5/26/14 Updated 4/27/16 TD = 11,525’ PBTD = 11,276’ MAX HOLE ANGLE = 55° @ 10,554’ RKB: 151’ / GL: 136’ AMSL KB – THF: 19.5’ H-7 DV @ 8,514 TOL 9,036’ CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor - - - Surf 28’ - unknown Surf. 13-д” Surf Csg 54.5 J-55 12.615” Surf 1,477’ 18- з” 1200 sx Surf. 13-д” DV Collar 1,477’ 1,479’ 13-д” 54.5 J-55 12.615” 1,479’ 2,981’ 600 sx 1,479’ 6-з” Prod Csg 28 P-110 5.791” Surf 92’ 10- з” 600 sx 6,700’ (Est) 6-з” 28 N-80 5.791” 92’ 6,671’ 6-з” 24 P-110 5.921” 6,671’ 8,514’ 6-з” DV Collar 8,514’ 8,516’ 6-з” 24 P-110 5.921” 8,516’ 9,380’ 600 sx 9,100’ (Est) 4” Liner 9.5 L-80 3.468” 9,036’ 11,403’ 5-з” 242 sx 9,544’ CBL TUBING DETAIL Cplg OD 3 ½ ”, EUE 8RD 9.3 L-80 2.992” 0’ 9,030’ 4.500” 20” 28’ 13-3/8” 2,017’ 6-5/8” 9,380’ 4” 11,403’ CBL EST 9,100’ CBL EST 6,700’ 1 5 6 7 4 8 9 X 2 3 JEWELRY DETAIL No. Depth ID OD Item 1 20’ 2.992” - Tubing Hanger, 3-1/2” 8RD Box x 3-1/2” 8RD Box 2 21’ 2.992” 3.500” Pups, 3-1/2” 8RD 3 4,108’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #3 (Live Valve) 4 6,993’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #2 (Live Valve) 5 8,500’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD Extra (Dummy) 6 8,953’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #1 (Orifice) 7 9,007’ 3.000” 5.500” Olgoonik AS1-X Mechanical Packer (24#-32#) 8 9,020’ 2.813” 4.438” X-Nipple 9 9,030’ 2.992” 4.438” WL Entry Guide 10 ? - - Fish (J-lugs and packer rubbers from 6-5/8” 24# AS1-X) LIH 5/23/14 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments H-1 10,591’ 10,623’ 10,294’ 10,312’ 6 32 60 11/16/17 Open H-2 10,623’ 10,644’ 10,312’ 10,325’ 6 21 60 11/16/17 Open H-3 10,660’ 10,685’ 10,334’ 10,349’ 6 25 60 11/08/17 Open H-4 10,700’ 10,715’ 10,358’ 10,366’ 6 15 60 3/29/18 Open H-5 10,754’ 10,779’ 10,389’ 10,404’ 6 25 60 11/08/17 Open H-5 10,798’ 10,804’ 10,415’ 10,419’ 6 6 60 11/08/17 Open H-5 10,831’ 10,851’ 10,435’ 10,447’ 6 19 60 11/08/17 Open H-5 10,910’ 10,950’ 10,484’ 10,510’ 6 40 60 05/31/14 2.5” Connex H-7 11,050’ 11,070’ 10,575’ 10,588’ 6 20 60 05/31/14 2.5” Connex Short Marker Joints @ 10,589'-10,599' MD @ 10,841'-10,851' MD @ 10,973'-10,992' MD CBL TOC 9,544’ Mrk Jt DV @ 1,477 H-5 Mrk Jt Mrk Jt Openhole 11,525’ 10 H-1 H-3 H-2 H-4 Updated by TCS 08-14-20 SCU 44B-33 PROPOSED SCHEMATIC Swanson River Unit Well SCU 44B-33 Completion Ran 5/26/14 TD = 11,525’ PBTD = 11,276’ MAX HOLE ANGLE = 55° @ 10,554’ RKB: 151’ / GL: 136’ AMSL KB – THF: 19.5’ H-7L H-7 H-9 H-12 DV @ 8,514 TOL 9,036’ CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor - - - Surf 28’ - unknown Surf. 13-д” Surf Csg 54.5 J-55 12.615” Surf 1,477’ 18- з” 1200 sx Surf. 13-д” DV Collar 1,477’ 1,479’ 13-д” 54.5 J-55 12.615” 1,479’ 2,981’ 600 sx 1,479’ 6-з” Prod Csg 28 P-110 5.791” Surf 92’ 10- з” 600 sx 6,700’ (Est) 6-з” 28 N-80 5.791” 92’ 6,671’ 6-з” 24 P-110 5.921” 6,671’ 8,514’ 6-з” DV Collar 8,514’ 8,516’ 6-з” 24 P-110 5.921” 8,516’ 9,380’ 600 sx 9,100’ (Est) 4” Liner 9.5 L-80 3.468” 9,036’ 11,403’ 5-з” 242 sx 9,544’ CBL TUBING DETAIL Cplg OD 3 ½ ”, EUE 8RD 9.3 L-80 2.992” 0’ 9,030’ 4.500” 20” 28’ 13-3/8” 2,017’ 6-5/8” 9,380’ 4” 11,403’ CBL EST 9,100’ CBL EST 6,700’ 1 5 6 7 4 8 9 X 2 3 JEWELRY DETAIL No. Depth ID OD Item 1 20’ 2.992” - Tubing Hanger, 3-1/2” 8RD Box x 3-1/2” 8RD Box 2 21’ 2.992” 3.500” Pups, 3-1/2” 8RD 3 4,108’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #3 (Live Valve) 4 6,993’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #2 (Live Valve) 5 8,500’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD Extra (Dummy) 6 8,953’ 2.992” 5.250” 3-1/2” SFO-1 Mandrel 8RD GLV #1 (Orifice) 7 9,007’ 3.000” 5.500” Olgoonik AS1-X Mechanical Packer (24#-32#) 8 9,020’ 2.813” 4.438” X-Nipple 9 9,030’ 2.992” 4.438” WL Entry Guide 10 ? - - Fish (J-lugs and packer rubbers from 6-5/8” 24# AS1-X) LIH 5/23/14 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments H-1 10,591’ 10,623’ 10,294’ 10,312’ 6 32 60 11/16/17 Open H-2 10,623’ 10,644’ 10,312’ 10,325’ 6 21 60 11/16/17 Open H-3 10,660’ 10,685’ 10,334’ 10,349’ 6 25 60 11/08/17 Open H-4 10,700’ 10,715’ 10,358’ 10,366’ 6 15 60 3/29/18 Open H-5 10,754’ 10,779’ 10,389’ 10,404’ 6 25 60 11/08/17 Open H-5 10,798’ 10,804’ 10,415’ 10,419’ 6 6 60 11/08/17 Open H-5 10,831’ 10,851’ 10,435’ 10,447’ 6 19 60 11/08/17 Open H-5 10,910’ 10,950’ 10,484’ 10,510’ 6 40 60 05/31/14 2.5” Connex H-7L 11,000 11,010’ 10,542’ 10,552’ 6 10 60 TBD - H-7 11,050’ 11,070’ 10,575’ 10,588’ 6 20 60 05/31/14 2.5” Connex H-9 11,100’ 11,120’ 10,614’ 10,634’ 6 20 60 TBD - H-12 11,425’ 11,450’ 10,831’ 10,856’ 6 25 60 TBD - Short Marker Joints @ 10,589'-10,599' MD @ 10,841'-10,851' MD @ 10,973'-10,992' MD CBL TOC 9,544’ Mrk Jt DV @ 1,477 H-5 Mrk Jt Mrk Jt Openhole 11,525’ 10 H-1 H-3 H-2 H-4 nilcnrp AlaA._ MAI DATE 11/07/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: AOGCC Natural Resources Technician 333 W. 71h Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 44113-33 (214-054) Production Profile CD: ANALYSIS FIELD -DATA 11/14/201810:45,,. Filefolder 11/14+'2018.10:45... Filefolder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this Received By:j I I I ` II �J ^I/� Date: /� RECEIVED NOV 14 2019 AOGCC 21 4054 31440 I or FAX to 907 777 E `, ED STATE OF ALASKA ilkKA OIL AND GAS CONSERVATION COILSION APR 2 6 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Qnhownei U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well [Ti Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 214-054 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-133-10170-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)44B-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,525 feet Plugs measured N/A feet true vertical 10,903 feet Junk measured Unknown feet Effective Depth measured 11,276 feet Packer measured 9,007 feet true vertical 10,726 feet true vertical 9,007 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2,981' 2,730 psi 1,130 psi Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367' 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCO E` - Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,030'MD 9,030'TVD Olgoonik AS1-X Packers and SSSV(type,measured and true vertical depth) Mechanical;N/A 9,007'MD 9,007'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 24 128 915 1210 395 Subsequent to operation: 28 201 1015 1230 395 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ 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: 318-109 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager �/ Contact Email: tkramer@hilcorp.com Authorized Signature: ( 41 Date: fisc,r Contact Phone: 777-8420 Form 10-404 Revised 4/2017 RBDMSJ APR 3 0 2018 c.(. (' Submit Original Only i • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 44B-33 E-Line 50-133-10170-01 214-054 3/29/18 3/29/18 Daily Operations: 03/29/2018-Thursday PTW and JSA. Spot and rig up equipment. Pressure test lubricator to 250 psi low and 3,500 psi high. Shut well in. Pump 15 gal of diesel down well. RIH w/2-1/2" x 15' Connex HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to perf from 10,700' to 10,715' (CCL/GR to top shot is 19.2'). Log up to stop depth at 10,680.8'. Fire gun with 1,250 psi on well. No pressure change after 15 min. POOH. All shots fired. Rig down equipment and turn well over to field. SCU 44B-33 Swanson River Unit Well SCU 44B-33 SCHEMATIC Completion Ran 5/26/14 HileorU Alaska,LLC Updated 4/27/16 RKB:151'/GL:136'AMSL KB-THF:19.5' CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 'S 1 "`"Al 20" Conductor - - - Surf 28' unknown Surf. 20" 2 E' 13-%" 54.5 J-55 12.615" Surf 1,477' 28' 13-%" Surf Csg DV Collar 1,477' 1,479' 18 1200 sx Surf. 11 � + 13-54" 54.5 1-55 12.615" 1,479' 2,981' 600 sx 1,479' 4 6%" 28 P-110 5.791" Surf 92' 6%" 28 N-80 5.791" 92' 6,671' iSe_l6-3/4" Prod Csg 24. P-110 5.921" 6,671' 8,514' 600 sx 6,700'(Est) 13-3/8" ra 3 1' 6-%" DV Collar 8,514' 8,516' s 2'017' 6-%" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL CBL EST TUBING DETAIL CpIgOD 6,700' T 3%",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 9,030' I I 4.500" kir`. air. 4 .. `" JEWELRY DETAIL 4 1 i No. Depth ID OD Item Q 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 2 21' 2.992" 3.500" Pups,3-1/2"8RD 5 " 3 4,108' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) 4 6,993' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Live Valve) _ 5 8,500' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD Extra(Dummy) _ 6 8,953' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice) 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 6 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LIH 5/23/14 I 7 = • 4 Short Marker Joints 8 @ 10,589'-10,599'MD all @ 10,841-10,851'MD TOL 9 @ 10,973'-10,992'MD 9,036' CBL EST 1,, N 9,100' r i „ziN 6-5/8" 'a: PERFORATIONS 9,380' ; %, Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments CBL TOC H-1 10,591' 10,623' 10,294' 10,312' 6 32 60 11/16/17 Open 9,544' ,,0; E,=s H-2 10,623' 10,644' 10,312' 10,325' 6 21 60 11/16/17 Open H-3 10,660' 10,685' 10,334' 10,349' 6 25 60 11/08/17 Open MrkJt x1 H-4 10,700' 10,715' 10,358' 10,366' 6 15 60 3/29/18)(. Open R H-1 H-5 10,754' 10,779' 10,389' 10,404' 6 25 60 11/08/17 Open el `` 1-1_2 H-5 10,798' 10,804' 10,415' 10,419' 6 6 60 11/08/17 Open ' IV . H-3 H-5 10,831' 10,851' 10,435' 10,447' 6 19 60 11/08/17 Open +, - H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 05/31/14 2.5"Connex MrkJt . ' 11-4 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 05/31/14 2.5"Connex H-5 I MrkJt GLV Port Temp @ t 10 H-7 # Size Depth TCF PSC PSO PTRO Description 4„ V. c II 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 -Ask 9" 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 11,403' �� .,%, }', s.r r„'tlt ' ;t„„ 't Openhole 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 .1 ' .f 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' Updated by DMA 04-18-18 OF Tit, THE STATE Alaska OSI and Gas ti ' .rjA ofeLIC T1 Conservation Commission #tint = = __ .,:___ - l 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF p. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC scolicx, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field,Hemlock Oil Pool, SCU 44B-33 Permit to Drill Number: 214-054 Sundry Number: 318-109 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, I \ Hollis S. French Chair DATED this ZI day of March,2018. RBDMSQ 14141 2 2 UV • 0 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 4 g 18 _J APPLICATION FOR SUNDRY APPROVALS D i nr 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate 0 Repair Well El Operations shutdown❑ Suspend 0 Perforate Q- Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill 0 Perforate New Pool El Re-enter Susp Well ❑ Alter Casing 0 Other: El 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 214-054 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10170-01-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B • Soldotna Creek Unit(SCU)44B-33 • Will planned perforations require a spacing exception? Yes 0 No ❑2 • 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028990 ' Swanson River Field/Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,525' ' 10,903' • 11,276' 10,726' -3,375 psi N/A Unkown Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2981' 2,730 psi 1,130P si Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367' 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,030' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Olgoonik AS1-X Mechanical;N/A 9,007'MD,9,007'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development❑2 • Service El 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: March 28,2018 OIL ❑0 • WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 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: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasse(7hilcorp.com Contact Phone: 777-8354 Authorized Signature: W.421' Date: 3/13/1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 517) - 10CI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes Noi, ❑ � Subsequent Form Required: /�"' o 1 4._..CC)r..„ - APPROVED BY r Approved by: ,�. COMMISSIONER THE COMMISSION Date: ?S \ RI SINArLR1301111 , Submit Form and 4 a 10-403 Revised 4/2017 Iii Approved application is MAR r7hrpp i. Dup catQ • • Well Prognosis Well: SCU 44B-33 Hilcor)Alaska,LLQ Date:3/14/2018 Well Name: SCU 44B-33 API Number: 50-133-10170-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: March 28th, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-054 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: —2,200 psi @ 10,219' TVD (Based on offset wells) Maximum Expected BHP: —4,397 psi @ 10,227' TVD (Original pressure gradient 0.43 psi/ft) Max. Potential Surface Pressure: — 3,375 psi (Based on a 0.1 psi/ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Hemlock in 1960 as SCU 14-34.The well was worked over in 1962 for gas lift conversion and again in 1973 for Hemlock zonal isolation. The casing scheme consists of a 13-3/8" surface casing @ 2891 and cemented to surface.A 10-5/8" hole was drilled to 10,870' and a 6-5/8" P-110 production casing was run.The well was worked over in April 2013 and a string of 2-7/8"tubing and a mechanical packer set above the Hemlock H-1 bench.The completion was pulled, plugged back, and sidetracked in April 2014 using the Saxon#169 rig.The completion was run using the Saxon#169 rig in May 2014 and perforated thru-tubing at the end of May 2014.The Hemlock H1, H2, H3, and H5 benches were added in November 2017. The purpose of this work/sundry is to add perforations in the Hemlock H4 bench. ' Brief Procedure: 1. MIRU e-line unit. Pressure Test lubricator to 3,500 psi Hi 250 Low. 2. SI and bleed tubing pressure down, as directed by Reservoir Engineer. 3. PU and RIH with perf guns. Log on depth and perforate the following intervals. Zone Sands Top (MD) Btm (MD) FT Hemlock H-4 ±10,697' ±10,735' 38' a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Gamma/CCL correlation log. e. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Hemlock&Tyonek G Pool based on 1 Conservation Order No. 123B. 4. RD E-line. 5. Turn Well over to Production. Attachments: 1. Actual Schematic 2. Proposed Schematic Te SCU 44B-33 Swanson River Unit Well SCU 44B-33 SCHEMATIC1Ufated4/27116completion Ran 5/26/14 IHiIcorp4iaskaLLC RKB:151'/GL:136'AMSL CASING DETAIL KB-THF:19.5' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 20" Conductor - - - Surf 28' - unknown Surf. 20" t 2 13-%" 54.5 J-55 12.615" Surf 1,477' 28' = ... 0 . 114 SCU 44B-33 Swanson River Unit Well SCU 44B-33 PROPOSED SCHEMATIC Completion Ran 5/26/14 Updated 4/27/16 Hilcorp Alaska.LLC RKB:151'/GL:136'AMSL KB-THF:19.5' CASING DETAIL Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 " s 20" Conductor - - - Surf 28' - unknown Surf. 20" ,2 - ,. 13-84" 54.5 J-55 12.615" Surf 1,477' 3.28' 13-%" SurfCsg DV Collar 1,477' 1,479' 18- 1200 sx Surf. .7- 13-84" 54.5 J-55 12.615" 1,479' 2,981' 600 sx 1,479' 11 1 IV 6-3/4" 28 P-110 5.791" Surf 92' 6-3/4" 1"" 28 N-80 5.79 92' 6,671' 10- 600 sx 6,700'(Est) .., y 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' %„ 13-3/8" : 3 1131 ai...1 6-%" DV Collar 8,514' 8,516' 2,017' 6-%" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 4" Liner 9.5 1-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL CBL ESTE.. TUBING DETAIL CplgOD 6,700' a ? 3 34",EUE 8RD 19.3 I 1-80 I 2.992" I 0' I 9,030' I I 4.500" r 4I 47.,-:' p JEWELRY DETAIL a 1 ' No. Depth ID OD Item 6 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 2 21' 2.992" 3.500" Pups,3-1/2"8RD 5 I Id 3 4,108' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 4 6,993' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Live Valve) 5 8,500' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice) 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 6 I hl 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 ? - Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LIN 5/23/14 3E I 7 - � Short Marker Joints 8 la4 @ 10,589'-10,599'MD @ 10,841'-10,851'MD TOL 9 @ 10,973'-10,992'MD 9,036' CBL EST 9,100' i 1, . 6-5/8" PERFORATIONS 9,380' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments CBL TOC H-1 10,591' 10,623' 10,142' 10,161' 6 32 60 11/16/17 Open 9,544' H-2 10,623' 10,644' 10,161' 10,174' 6 21 60 11/16/17 Open H-3 10,660' 10,685' 10,183' 10,197' 6 25 60 11/08/17 Open Mrk Jt H-4 10,697' 10,735' 10,205' 10,227' 38 TBD Proposed ., H4 H-5 10,754' 10,779' 10,238' 10,253' 6 25 60 11/08/17 Open H-2 H-5 10,798' 10,804' 10,264' 10,267' 6 6 60 11/08/17 Open H-3 H-5 10,831' 10,851' 10,284' 10,296' 6 19 60 11/08/17 Open Mrk Jr A. H-4 H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 05/31/14 2.5"Connex H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 05/31/14 2.5"Connex H-5 GLV Port Temp @ Mrk Jt t' # Size Depth TCF PSC PSO PTRO Description ;. H-7 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 10 ` Ill20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 a" - ' ;-,lie * 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 11,403' Openhole 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' Updated by TWN 3-14-18 STATE OF ALASKA • RECEIVED ALAIPA OIL AND GAS CONSERVATION COMMISSION DEC 1 3 2011 REPORT OF SUNDRY WELL OPERATIONS ACC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing Li Operations shutdown U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 214-054 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-133-10170-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)44B-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,525 feet Plugs measured N/A feet true vertical 10,903 feet Junk measured Unknown feet Effective Depth measured 11,276 feet Packer measured 9,007 feet true vertical 10,726 feet true vertical 9,007 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2,981' 2,730 psi 1,130 psi Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367' 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation depth Measured depth See Attached Schematic pp� True Vertical depth See Attached Schematic DF7E 1 .`,,,,,i, 2 C# 1.. } Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,030'MD 9,030'TVD Olgoonik AS1-X Packers and SSSV(type,measured and true vertical depth) Mechanical;N/A 9,007'MD 9,007'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 78 315 752 1380 400 Subsequent to operation: 61 201 810 1160 385 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ 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: 317-496 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: OperationsOp�� Manager Contact Email: tkramerna.hilcoro.com y4Authorized Signature: �i2%GDate: 1Z/t31i 7 Contact Phone: 777-8420 /Z -iV-17 Form 10-404 Revised 4/2017 (�� RBDMS 3 2017 Submit Original Only • ! Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 44B-33 SL/E-Line 50-133-10170-01 214-054 10/31/17 11/16/17 Daily Operations: 10/31/2017-Tuesday Arrive @ Swanson River, talk w/company rep, sign permits.TGSM. Grab equipment from bull rail. Rig up.TP-400 psi. PT 2,500 psi, good. RIH w/2.65" G-ring to 11,110' KB. POOH. OOH w/G-ring, no parrafin on tools. RIH w/25' of 2.5 spent guns (5' X 5") to 11,090' KB. POOH. OOH w/guns. No obstructions. FL- 8,800' ??. Begin rig down. Rigged down. Fill up equipment, sign out, turn in permits. Depart Swanson River for PWL shop. 11/08/2017-Wednesday Sign in. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator. Pressure test to 250 psi low and 3,500 psi. TP-400 psi. Shut well in. RIH w/2-1/2" x 20' Millennium HC, 6 spf, 60 deg phase, tied into OHL and stop at 10,928' (did not sit down). Ran correlation log and send to town. Get ok to perf from 10,831'to 10,851'. Spotted and fired gun#1 with 1,950 psi on tubing. No change in tubing. POOH. All shots fired. RIH w/2-1/2" x 6' Millennium HC, 6 spf, 60 deg phase and tied into OHL. Ran correlation log and send to town. Get ok to perf from 10,798' to 10,804'. Spotted and fired gun #2 with 1,950 psi on tubing. No change in tubing pressure. Started out of hole and air line froze up on grease unit. Got heater from field and put on skid. Got air hose and compressor dried out. POOH. All shots fired. RIH w/2- 1/2" x 20' Millennium HC, 6 spf, 60 deg phase and tied into OHL.Tools sat down at 10,864'. Pulled 600#over line wt to get loose. Ran correlation log and send to town. Shifted log up 1'. Get ok to perf from 10,759' to 10,779' . Spotted and fired gun#3 with 1,950 psi on tubing. No change in tubing pressure. POOH. All shots fired. RIH w/2-1/2" x 5' Millennium HC, 6 spf, 60 deg phase and tied into OHL. Ran correlation log and send to town. Get ok to perf from 10,754' to 10,759'. Spotted and fired gun #4 with 1,950 psi on tubing. No change in tubing. POOH. All shots fired. No change in pressure. Rig down lubricator and turn well over to field. 11/16/2017-Thursday Sign in. Mobe to location. PTW and JSA. Spot equipment. Rig up lubricator. Grease pump was froze up. Put heater on it. Fixed pump. Pressure test to 250 psi low and 3500 psi.TP- 1350 psi. Shut well in. RIH w/2-1/2"x25' Razer HC, 6 spf, 60 deg phase and tied into OHL . Ran correlation log and send to town. Get ok to perf from 10,660' to 10,685'. Spotted and fired gun #1 with 1350 psi on tubing. After 5 min—1350 psi, 10 min—1355 psi, 15 min— 1365 psi, 30 min— 1375 psi and 60 min— 1395 psi. POOH. All shots fired. RIH w/2-1/2"x33' Razer HC, 6 spf, 60 deg phase and tied into OHL. Ran correlation log and send to town. Get ok to perf from 10,611'to 10644' . Spotted shot and fired gun #2 with 1430 psi on tubing. 5 min—1440 psi, 10 min—1455 psi, 15 min—1475 psi. Out of hole 1500 psi. All shots fired. RIH w/2- 1/2"x20' Razer HC, 6 spf, 60 deg phase and tied into OHL. Ran correlation log and send to town. Get ok to perf from 10,611' to 10,591' . Spotted shot and fired gun #3 with 1500 psi. After 5 min—1515 psi, 10 min— 1515 psi, 15 min— 1520 psi, 30 min— 1540 psi and in lubricator was 1585 psi. All shots fired. Rig down lubricator and turn well over to field. • SCU 446-33 Swanson River Unit 410 Well SCU 44B-33 ' PROPOSED SCHEMATIC Ran Updated7/16 Hilcoru Alaska,LLC RKB:151'/GL:136'AMSL CASING DETAIL KB-THF:19.5' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 !w 20" Conductor - - - Surf 28' unknown Surf. 20" , 2 I #t 13-94" 54.5 J-55 12.615" Surf 1,477' 28' . 1• 3-94 Surf Csg DV Collar 1,477' 1,479' 18- 1200 sx Surf. 13 94" 54.5 J-55 12.615" 1,479' 2,981' / 600 sx 1,479' �r 6-%" 28 P-110 5.791" Surf 92' q'_- 6-%" 28 N-80 5.791" 92' 6,671' + 10- 600 sx 6,700'(Est) ''k 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' %„ 13-3/8" °.,� 3 , i1 6-3/4" DV Collar 8,514' 8,516' 2,017' { 6-3/4" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL CBL EST?, -irTUBING DETAIL CplgOD a . 6,700' 3''A",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 9,030' I I 4.500" 1L t w, JEWELRY DETAIL I 1A No. Depth ID OD Item 0 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 2 21' 2.992" 3.500" Pups,3-1/2"8RD SI it 3 4,108' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 4 6,993' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Live Valve) 5 8,500' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice) 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 61 IN 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 7 Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LIH 5/23/14 7 1 Z Short Marker Joints 8 @ 10,589'-10,599'MD @ 10,841'-10,851'MD TOL 9 , @ 10,973'-10,992'MD 9,036' _ ei CBL EST If 9,100' r% zi - 6-5/8" 'I, PERFORATIONS 9,380' ' Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments CBL TOC " H-1 10,591' 10,623' 10,142' 10,161' 6 32 60 11/16/17 Open 9,544' t"l H-2 10,623' 10,644' 10,161' 10,174' 6 21 60 11/16/17 Open sJ H-3 10,660' 10,685' 10,183' 10,197' 6 25 60 11/08/17 Open H-5 10,754' 10,779' 10,238' 10,253' 6 25 60 11/08/17 Open Mrk Jt t" ! i -. 11-2 H-1 H-5 10,798' 10,804' .. 10,264' 10,267' 6 6 60 11/08/17 Open H 2 H-5 10,831' 10,851' 10,284' 10,296' 6 19 60 11/08/17 Open t :" H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 05/31/14 2.5"Connex 0* f, H-3 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 05/31/14 2.5"Connex MrkJt t H-5 "; 11-5 GLV Port Temp @ $ # Size Depth TCF PSC PSO PTRO Description MrkJt 10 e. H-7 20 1310.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 g PI 11 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 9 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 11,403' '.,,. s r ,';,,, NOpenhole i"$_ 1 ^s 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' Updated by DMA 12-13-17 z`4-osq • ID Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 RECEIVED Anchorage, 99503 Tele: 907 77777 8308 Hilts-07.410411.LL: Fax: 907 777-8510 DEC 15 2017 E-mail: snolan@hilcorp.com DATA LOGGED iso/201$ K BENDER DATE 12/05/2015 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL 4NNED r" ® 6 2 r? SCU 44B-33 Prints: PERF RECORD CD: 1 DATA ( j 5CU 449-33 PERF 08NOV17 LAS.zip 11/15,0)17 3:54 PM Compressed(zippe... 78 KB .1),M SCU 44B-33_PERF 08NOV17.pdf 11/15/2017 2:18 PM Adobe Acrobat Doc... 899 KB u SCU 44B-33 PERF 08NOV17 img.bf 11/15/2017 2:18 PM TIF File 2,944 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: /� �� Rate: 1i vOF Tit • =>�\\I%% sA THE STATE Alaska Oil and Gas tz; tfLAsiKA Conservation Commission ux 7._ 333 West Seventh Avenue lerGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager CW" NOV 0 9 2017, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 44B-33 Permit to Drill Number: 214-054 Sundry Number: 317-496 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, (b4 Hollis S. French Chair DATED this ' day of October, 2017. REDcJS 1-k- Vll7 - 2231 • • ECE1VED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 1100, ' APPLICATION FOR SUNDRY APPROVALS n7 S to Z6/7 20 MC 25.280 A OG 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑✓ . Other Stimulate El Pull Tubing 0 Change Approved Program El Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska, LLC Exploratory 0 Development ❑✓ . 214-054 . 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10170-01-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes IDNo 0Soldotna Creek Unit(SCU)44B-33 ' 9. Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990 Swanson River Field/Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 11,525' • 10,903' • 11,276' , 10,726' • -3,410 psi N/A Unkown Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2981' 2,730 psi 1,130 psi Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,030' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Olgoonik AS1-X Mechanical;N/A 9,007'MD,9,007'ND; N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development 2 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: November 1,2017 OIL ❑✓ - WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com Contact Phone: 777-8420 Authorized Signature: `j% ,�� Date: 10/i 7// 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: //M CP Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ rrr 1.;,:: rwa.. Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0 Li O 1 RED rrc3 LL, l; �r -' i EU i/ APPROVED BY ` Approved by: _ter COMMISSIONER THE COMMISSION Date: t U t Z.b (t- �( +� \ /c -2,-(-,? �Y., Submit Form and V- i� Form 10-403 Revised 4/2017 Approved application is 1(1d� It GottNinpc ate of approval. O�{lt ments in Duplicate ,S 11 iK\ {' /s l �j 7 ./a,.4 5./I Well Prognosis Well: SCU 44B-33 Hileorp Alaska,LU Date: 10/17/2017 Well Name: SCU 44B-33 API Number: 50-133-10170-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: November 1, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-054 First Call Engineer: Ted Kramer (907)777-8420 (0) (985)867-0665 (M) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 227-5293 AFE Number: Current Bottom Hole Pressure: —2,200 psi @ 10,219' TVD (Based on offset wells) Maximum Expected BHP: —4,469 psi @ 10,219' TVD (Calc'd Virgin Bottom Hole Pressure) Max. Potential Surface Pressure: — 3,410 psi (Based on a 0.1 psi/ft gas gradient Brief Well Summary This well was drilled and completed as an oil well in the Hemlock in 1960 as SCU 14-34.The well was worked . over in 1962 for gas lift conversion and again in 1973 for Hemlock zonal isolation. The casing scheme consists of a 13-3/8" surface casing @ 2891 and cemented to surface. A 10-5/8" hole was drilled to 10,870' and a 6-5/8" P-110 production casing was run.The well was worked over in April 2013 and a string of 2-7/8"tubing and a mechanical packer set above the Hemlock H-1 bench.The completion was pulled, plugged back, and sidetracked in April 2014 using the Saxon#169 rig.The completion was run using the Saxon#169 rig in May 2014 and perforated thru-tubing at the end of May 2014. The purpose of this work/sundry is to add perforations in the Hemlock H1. H2, H3, H5 benches. Notes Regarding Wellbore Condition • Wellbore maximum deviation is 54.5 degrees(vertical to 9,380' MD). / Brief Procedure: 1. MIRU e-line unit. Pressure Test lubricator to 3,500 psi. 2. PU and RIH with perf Guns. Log on depth and perforate the following intervals. Zone Sands Top (MD) Btm (MD) FT Hemlock H-1 ±10,591' ±10,623' 32' Hemlock H-2 ±10,623 ±10,644 21 Hemlock H-3 ±10,660 ±10,685 25 Hemlock H-5 ±10,754 ±10,779 25 Hemlock H-5 ±10,798 ±10,804 3 Hemlock H-5 ±10,831 ±10,851 19 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Gamma/CCL correlation log. e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Hemlock&Tyonek G Pool based on Conservation Order No. 123B. .11 • • Well Prognosis Well: SCU 44B-33 Hilcorp Alaska,LLQ Date: 10/17/2017 3. RD E-line. 4. Turn Well over to Production. Attachments: 1. Actual Schematic 2. Proposed Schematic i t:EN SCU 44B-33 well SCU44BF Snit Completion Ran 5/26/14 • Actual Schematic Updated 4/27/16 IHileorpAjaska,LLC RKB:151'/GL:136'AMSL Casing & Tubing KB—THF:19.5' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top '" 1 ' • 20" Conductor - Surf 28' - unknown Surf. 20" 2 13-%" J-55 12.615" Surf 1,477' 28' '1.''' 13%" Surf Csg DV Collar 1,477' 1,479' 18-%" 1200 sx Surf. . rii / ..,,, 13-%" ' 54.5 J-55 12.615" 1,479' 2,981' 600 sx 1,479' 6-%a" 28 P-110 5.791" Surf 92' 6-%" 28 N-80 5.791" 92' 6,671' c) 4.,...01: t 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' 10-%" 600 sx 6,700'(Est) 6-%" DV Collar 8,514' 8,516' 13-3/8" 3 ii '/ 6-%" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 2,017' 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL Tubing Cplg OD 3%",EUE 8RD I 9.3 I L-80 I 2.992" I 0' I 9,030' ' ru 4.500" CBL EST'.t 6,700' -.+1. JEWELRY DETAIL 4 No. Depth ID OD Item 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box •r 41 IN _` 2 21' 2.992" 3.500" Pups,3-1/2"8RD 3 4,108' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) CI :ri4 6,993' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Live Valve) 0 5 8,500' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice) 5 I IN 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LIH 5/23/14 61 Short Marker Joints @ 10,589'-10,599'MD *T--- @ 10,841'-10,851'MD I t_.. I @ 10,973'-10,992'MD 7 = 8 TOL 9 MIR 9,036' CBL EST `' = "' PERFORATION DETAIL 9,100' i 41,;. Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9-3 ''.1., ; *. 5/31/14 H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 2.5"Connex 9,38080' * 7,4 7 5/31/14 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 2.5"Connex CBL TOC :I, 9,544' f i -` GLV Port Temp @ MrkJt # Size Depth TCF PSC PSO PTRO Description r 20 131 0.856 1692 2000 2130 IPOR-1/1POC-1/PPOR-1 .+ 20 167 0.799 1662 1861 2095 IPOR-1/1POC-1/PPOR-1 ',,* q, 20 191 0.765 1552 1747 1995 IPOR-1/1POC-1/PPOR-1 MrkJt) ,' riH, M.r'" ,, H-5 MrkJt '' 10 " 11-7 V. 4 , 11,403 a i �, nhole '1 f r• 1 1 " O11e525' TD=11,525' t PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' SCU 44B-33 Actual Schematic 4-27-2016 Updated by JEK 4-27-16 0 • SCU 44B-33 Swanson Well SCU 44Br Snit PROPOSED SCHEMATIC Completion Ran 5/26/14 MAI Updated 4/27/16 RKB:151'/GL:136'AMSL KCASING DETAIL KB 19.5' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 f 20" Conductor - - - Surf 28' - unknown Surf. 20" . 2 - 13-%" 54.5 J-55 12.615" Surf 1,477' 28' 13-%" Surf Csg DV Collar 1,477' 1,479' 18 1200 sx Surf. 41 -- 13-%" 54.5 1-55 12.615" 1,479' 2,981' 600 sx 1,479' 6-3/4" 28 P-110 5.791" Surf 92' rl 44 ' 6-%" 28 N-80 5.791" 92' 6,671' 10- } 600 sx 6,700'(Est) , , 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' 13-3/8" ra 3 6-%" DV Collar 8,514' 8,516' 2,017' 6-%" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL CBLEsrTUBING DETAIL CplgOD 6,700' # 1 3%",EUE 8RD 19.3 I L-80 2.992" I 0' I 9,030' I I 4.500" t? JEWELRY DETAIL ■ No. Depth ID OD Item - 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 2 21' 2.992" 3.500" Pups,3-1/2"8RD 5 I til 3 4,108' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) 4 6,993' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Live Valve) 5 8,500' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice) 79,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 61' IV 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 ? - - Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LII-15/23/14 ® I I 7 , 11 Short Marker Joints 8ila @ 10,589'-10,599'MD 1 @ 10,841-10,851'MD TOL 9 ' ;. @ 10,973'-10,992'MD 9,036' CBL EST "4 9,100' ii 6-5/8" ' �4'` PERFORATIONS 9,380' ".I :, Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Date Comments CBL TOC ` H-1 ±10,591' ±10,623' ±10,142' ±10,161' 6 32 60 Proposed TBD 9,544' I.a H-2 ±10,623' ±10,644' ±10,161' ±10,174' 6 21 60 Proposed TBD '' Ery H-3 ±10,660' ±10,685' ±10,183' ±10,197' 6 25 60 Proposed TBD Mrk Jt±° H-5 ±10,754' ±10,779' ±10,238' ±10,253' 6 25 60 Proposed TBD ,, 4 H-1 H-5 ±10,798' ±10,804' ±10,264' ±10,267' 6 6 60 Proposed TBD '-. 11-2 H-S ±10,831' ±10,851' ±10,284' ±10,296' 6 19 60 Proposed TBD ` H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 5/31/14 2.5"Connex 1. -$ H-3 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 5/31/14 2.5"Connex Mrk JtIt. `+.` H-5 " I ' F. 11-5 ,; GLV Port Temp @ Mrk Jt- # Size Depth TCF PSC PSO PTRO Description 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 10 0 H 7 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 a a4 . 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 11,403 .r�t ?r. r t r ty , Openhole '' 1 " 44"44'. 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' Updated by DMA 10-17-17 • • Carlisle, Samantha J (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, February 22, 2017 9:11 AM To: Donna Ambruz Cc: Chad Helgeson;Joe Kaiser;Carlisle, Samantha J (DOA) Subject: RE: Sundry Cancellation - Sundry#316-258 SCU 44B-33 (PTD 214-054) Donna, Sundry#316-258 will be withdrawn as requested. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Donna Ambruz [mailto:dambruz@hilcorp.com] Sent:Tuesday, February 21, 2017 3:15 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Chad Helgeson <chelgeson@hilcorp.com>;Joe Kaiser<jkaiser@hilcorp.com> Subject:Sundry Cancellation -Sundry#316-258 SCU 44B-33 (PTD 214-054) Guy, Please withdraw the above mentioned sundry. Thank you. Donna thn5'twz SCANNED of 4 Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310- Fax dambruz@hilcorp.com 1 RB S (\-4;;, C s,' OF TFJ 4,1"`' ,1" / THE STATE Alaska Oil and Gas tib,^�i�aM OfAL /` sKA. Conservation Commission sof 333 West Seventh Avenue lt � GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Off,, ; )' Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson SCAMS my Operations Manager 1; Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 44B-33 Permit to Drill Number: 214-054 Sundry Number: 316-258 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this ) day of May, 2016. RBDMS l,t/ L„`( 1 1 2016 • 0RECEIVED STATE OF ALASKA MAY 03016 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 j//, /f 4, APPLICATION FOR SUNDRY APPROVALS ,. 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Re-run cap string R 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development ❑✓ • 214-054 ' 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10170-01 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)44B-33 ' Will planned perforations require a spacing exception? Yes ❑ No ❑., 9. Property Designation(Lease Number): 10.Field/Pool(s): FEDA028990 ' Swanson River Field/Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,525' ' 10,903' . 11,276' , 10,726' 619 psi N/A Unkown Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2981' 2,730 psi 1,130 psi Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367' 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 9,030' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Olgoonik AS1-X Mechanical;N/A 9,007'MD,9,007'TVD;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic El13.Well Class after proposed work: yt�,.(,'`y Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development I71f/ Service ❑ 14. Estimated Date for 15.Well Status after proposed work: May 17,2016 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email_ jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature Phone 907-777-8405 Date Sl 17/i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number � \Le - 25 ' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes LI No ©` Subsequent Form Required: /< - '`1' 'i RBDMS U p:`;\'( 1 1 2016 APPROVED BY Approved by: P2.4,,,„4_,... nn COMMISSIONER THE COMMISSION Date: .5"...../( _ Lb �� I iAditQf _+ �/'jam Submit Form and Form 10-403 evised 11/2015 4411 i n 12 months from the date of approval. 111 Attachments in Duplicate 7b .1--. 4:.. /lc • Well Prognosis Well: SCU 44B-33 :Uaa.ka.i.i.c Date:05/03/2016 Well Name: SCU 44B-33 API Number: 50-133-10170-01 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: May 17th, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-054 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: — 1,671 psi @ 10,519' TVD (Based on PT Survey 4-27-16) Maximum Expected BHP: — 1,671 psi @ 10,519' TVD (Based on PT Survey 4-27-16) Max. Potential Surface Pressure: —619 psi (Based on gradient 0.1 psi/ft) Brief Well Summary This well was sidetracked in April 2014 using the Saxon #169 rig.The completion was run using the Saxon #169 rig in May 2014 and perforated thru-tubing at the end of May 2014 as gas lifted oil well. In June 2014, a 3/8" capstring was installed to manage emulsion issues. In April 2016, the capstring was pulled to perform slickline work and run a PT survey. The purpose of this work/sundry is to re-install a 3/8"capstring. Notes Regarding Wellbore Condition • Wellbore maximum deviation is 54.5 degrees(vertical to 9,380' MD). • Well does not have a SSSV system,only a SSV system. Capstring Procedure: 1. MIRU Cap String Truck, PT lubricator to 2,500 psi Hi 250 Low. 2. Install new wellhead packoff. a. Current tree is 3.5" Bowen. 3. PU 3/8" capillary string. RIH and set at+/-9,025'. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • •! SCU 44B-33 Swanson River Unit Well SCU 44B-33 Actual Schematic Completion Ran 5/26/14 ill ilcorpAlaska,LLc Updated 4/27/16 RKB:151'/GL:136'AMSL C a s i n • & T u b i n • KB—THF:19.5' Size =NM Wt Gr.de ID To 1 Btm Hole Cmt Cmt To I 1 - 20" Conductor - - - Surf 28' - unknown Surf. 20" 2 I 13'A" 54.5 J-55 12.615" Surf 1,477' 28' 13'/•" Surf Csg DV Collar 1 477' 1,479' 18-%" 1200 sx Surf. t 13-A 54.5 J-55 12.615" 1,479' 2,981' 600 sx 1 479' • 6-'A" 28 P-110 5.791" Surf 92' 6-A' 28 N-80 5.791" 92' 6,671' 600 sx 6,700'(Est) 5 6-'A" Prod Csg 24 P-110 5.921" 6 671' 8,514' 10-%" 6-'A" DV Collar 8 514' 8,516' 13-3/8" 3 lilMilil 6-'A" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100' st 2,017' 4" Liner 9.5 L-80 3.468" 9 036' 11 403' 5-%s" 242 sx 9,544'CBL Tubin' C.I'OD 3%,",EUE 8RD 9.3 L-80 2.992" 0' 9,030' _ 4.500" CBL EST 6,700' . + JEWELRY DETAIL Y; No. Depth ID OD Item 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 4—1 ' 2 21' 2.992" 3.500" Pups,3-1/2"8RD 3 4,108' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) ' 4 6,993' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Live Valve) n 5 8,500' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice) 5 4111.11D1 7 9,007' 3.000" 5.500" OlgoonikAS1-X Mechanical Packer(24#-32#) 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LIH 5/23/14 6 ii1111i1 `'` Short Marker Joints @ 10,589'-10,599'MD @ 10,841'-10,851'MD 1I @ 10,973'-10,992'MD I 8 M TOL 9 —7%,- 9,036' -1 CBL EST 17,A ,i PERFORATION DETAIL 9,100' r; ''s Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9,380' 2' 5/31/14 H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 2.5"Connex 4 5/31/14 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 2.5"Connex CBL TOC 9,544' ' k1 Mrk Jt"'� GLV Port Temp @ # Size Depth TCF PSC P5O PTRO Description . ' •} 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 s.. 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 ?F 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 MrkJt i Jr.le .11 H-5 k V. MrkJt '' 10 -; H-7 r; 4n ! w .• t.k, 11,403' J, ' ., ,r '1 irr 2 ry't Openhole 1. , r. ik 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' SCU 44B-33 Actual Schematic 4-27-2016 Undated by JEK 4-27-16 Prop 44B-33 Swanson River Unit Well SCU 44B-33 Proosed Schematic Completion Ran 5/26/14 Hilcorp Alaska,LL(. j Updated 5/3/16 RKB:151'/GL:136'AMSL Casing & Tubing KB-THF:19.5' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 20" Conductor Surf 28' unknown Surf. 20" �' 2 13-%" 54.5 J-55 12.615" Surf 1,477' 28' 13%" Surf Csg DV Collar 1,477' 1,479' 18-%" 1200 sx Surf. • 13-%" 54.5 J-55 12.615" 1,479' 2,981' 600 sx 1,479' �' 6-%" 28 P-110 5.791" Surf 92' 6-%" 28 N-80 5.791" 92' 6,671' c 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' 10-%" 600 sx 6,700'(Est) 6-%" DV Collar 8,514' 8,516' 13-3/8" 3 % 6-%" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 2,017' 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL Tubing Cplg OD 3 Y2",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 9,030 ,,,w ' n^_''''44X44:-.4,,( 4.500" CBL EST 6,700' 4 JEWELRY DETAIL No. Depth ID OD Item 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 4 1r 2 21' 2.992" 3.500" Pups,3-1/2"8RD a' 3 4,108' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) @) I ' 4 6,993' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2(Live Valve) 0 5 8,500' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice) 5 ' 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 Fish(1-lugs and packer rubbers from 6-5/8"24#A51-X) 6 LIH 5/23/14 —61 Short Marker Joints @ 10,589'-10,599'MD @ 10,841'-10,851'MD I _Ilr 1 @ 10,973'-10,992'MD 7 = _ IICapillary String I 8 II 3/8" 2205 Stainless Steel(10,300'spool) Top Bottom ILI MD 0' 9,025' TOL 9 Z TVD 0' -9,025' 9,036' CBL EST PERFORATION DETAIL 9,100' sks os 4 " Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 6-5/8" 4 d,i 9,380' 5/31/14 H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 2.5"Connex f, 5/31/14 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 2.5"Connex CBL TOC 9,544' MrkJt'" GLV Port Temp �a Size Depth TCF PSC PSO PTRO Description d 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 ,,,r r, 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 V 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 MrkJt n H-5 44 Mrk Jt 4" 10 = H-7 tat 4" r . t..t", 11,403' ,, . -,r': it S ' Openhole r 2 1 r,� 1' 1,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' SCU 44B-33 Proposed Schematic 5-3-16 Updated by JEK 5/3/16 RECEIV , ,. STATE OF ALASKA ALAIIA OIL AND GAS CONSERVATION COMOION APR 2 9 2016 REPORT OF SUNDRY WELL OPERATIONS 'f‘ OGr 1.Operations Abandon U Plug Perforations E Fracture Stimulate _j Pull Tubing[J Operations shutdown _] Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Pull Captstring_ ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development E Exploratory ❑ 214-054 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10170-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)44B-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,525 feet Plugs measured N/A feet true vertical 10,903 feet Junk measured Unknown feet Effective Depth measured 11,276 feet Packer measured 9,007 feet true vertical 10,726 feet true vertical 9,007 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2,981' 2,730 psi 1,130 psi Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367' 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,030'MD 9,030'TVD Olgoonik AS1-X Packers and SSSV(type,measured and true vertical depth) Mechanical;N/A 9,007'MD 9,007'TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 104 4 312 1325 400 Subsequent to operation: 96 16 305 1300 440 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations EExploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ 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: N/A Contact Joe Kaiser-777-8393 Email jkaiser(a�hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature � /Z/7 ', ,Y Phone 907-777-8405 Date `f/?`di( Form 10-404 Revised 5/2015 74 C-3-1,67// U\- RBDMS " y- ki-,( 0 2 2016 Submit Original Only • • /I Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 44B-33 NA 50-133-10170-01 214-054 4/23/16 4/24/16 Daily Operations: 04/23/2016-Saturday Pump 100 bbls hot oil down tbg. 04/24/2016-Sunday RU cap string pulling equipment and pull 9,000' of 3/8" cap string from well. All cap string was recovered. wanson SCU 44B-33 well SCU 44Br Unitn • Actual Schematic Completion Ran 5/26/14 IHikorpAlaska,LLC Updated 6/17/14 RKB:151'/GL:136'AMSL Casing & Tubing KB—THF:19.5' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 1 20" Conductor - - - Surf 28' - unknown Surf. 20" �, 2 —filil13-%" 54.5 J-55 12.615" Surf 1,477' 28' ' 13-%" Surf Csg DV Collar 1,477' 1,479' 18_'/" 1200 sx Surf. 13-%" 54.5 J-55 12.615" 1,479' 2,981' 600 sx 1,479' 6-%" 28 _ P-110 _ 5.791" Surf 92' n 6-%" 28 N-80 5.791" 92' 6,671' 600 sx 6,700'(Est) . 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' 10-%" 4iiiiik6-% DV Collar 8,514' 8,516' 13-3/8" 3 ^ 6-%" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 2,017' 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL Tubing Cplg OD 3 V",EUE 8RD 19.3 I L-80 I 2.992" I 0' I 9,030' µ t„„ ', 4.500" CBL EST 6,700' , JEWELRY DETAIL �7',47 No. Depth ID OD Item `.' 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box - 4 I hl r 2 21' 2.992" 3.500" Pups,3-1/2"8RD 3 4,108' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) @) I 1 ' 4 6,993' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2(Live Valve) a 5 8,500' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" _ 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice) 5 I Id 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 ? Fish(1-lugs and packer rubbers from 6-5/8"24#AS1-X) 61 I LIH 5/23/14 111 Short Marker Joints ® 10,589'-10,599'MD @ 10,841'-10,851'MD MDDI @ 10,973'-10,992 MD ,,,, 7 - L: „cd_; I 8 1.1 TOL 9 '� 9,036' -I CBL EST i, '. PERFORATION DETAIL 9,100' 4i.• l' -i. Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments ✓,a 1,. 9,380' :,1 ti! 5/31/14 H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 2.5"Connex `" 5/31/14 H-7 11,050' 11,070' 10,575' 10,588' 6 20 60 2.5"Connex CBL TOC , '}' 9,544' tk F' k .'t CL`:` Port Temp ; MrkJt # 5+z-' De.:A" TCF PSC: PSC) PTRC) Description 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 L� ,. 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 ?'` 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 MrkJt " 1 r „ H-5 G MrkJt •.° 10 K} 11-7 ' ; :;A 4" 1+ ++s,,,,° .,� i tI 11,403' .m ', ' /a - t "s - Openhole ')< 0'' • �1ti 1` 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' SCU 44B-33 Actual Schematic 4-27-2016 Updated by JEK 4-27-16 T— STATE OF ALASKA ALAS )IL AND GAS CONSERVATION COMMIS, J REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Install Capstring Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: (Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 214-054 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-10170-01 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028990 Soldotna Creek Unit(SCU)44B-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Hemlock Oil 11.Present Well Condition Summary: EC Elul ED J Total Depth measured 11,525 feet Plugs measured N/A `feet true vertical 10,903 feet Junk measured Unknown feet ,jUL 2 1 2.014 Effective Depth measured 11,276 feet Packer measured 9,007 feet GAO true vertical 10,726 feet true vertical 9,007 feet - Casing Length Size MD ND Burst Collapse Structural Conductor 28' 20" 28' 28' Surface 2,981' 13-3/8" 2,981' 2,981' 2,730 psi 1,130 psi Intermediate Production 9,380' 6-5/8" 9,380' 9,380' 8,810 psi 6,710 psi Liner 2,367' 4" 11,403' 10,815' 7,910 psi 6,590 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 9,030'MD 9,030'ND Olgoonik AS1-X Packers and SSSV(type,measured and true vertical depth) Mechanical;N/A 9,007'MD 9,007'ND N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descnptions including volumes used and final pressure: N/A 13. Representative Daily Avera A f6n or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 259 44 526 1,420 300 Subsequent to operation: 283 0 526 1,390 285 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑] Gas El WDSPL❑ 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: 314-363 Contact Stan Porhola Email sporholac hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature .. /6-14.------. 1iPhone 907-777-8412 Date Zll( /L f L RBCMS JUL 2 2 'Ai" r Form 10-404 Revised 10/2012 ,c/L 7/9/V Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date • SCU 44B-33 50-133-10170-01 214-054 6/17/14 6/17/14 Daily Operations: 06/17/2014-Tuesday Rig Up Cap String Truck. Rig up lubricator and 3-1/8" flanged adapter. Test to 3,000 psi -test OK. RIH w/3/8" capillary string. Set capillary string @ 9,025'. RDMO Cap String Truck. • SCU 44B-33 Swanson River Unit Well SCU 44B-33 Actual Schematic Completion Ran 5/26/14 HilcorpAlaska.LLC Updated 6/17/14 RKB:151'/GL:136'AMSL Casing & Tubing KB—THF:19.5' Size Type I Wt Grade ID Top Btm Hole Cmt Cmt Top rte, I _ Y�A 20" Conductor - - - Surf 28' - unknown Surf. 20" , 2 _ 13-%" 54.5 J-55 12.615" Surf 1,477' 1200 sx Surf. 28, _ 13-%" Surf Csg DV Collar 1,477' 1,479' 18%" N 13-%" 54.5 J-55 12.615" 1,479' 2,981' 600 sx 1,479' yr 6-%" 28 P-110 5.791" Surf 92' @}"'� r' 6-%" 28 N-80 5.791" 92' 6,671' o i 6-%" Prod Csg 24 P-110 5.921" 6,671' 8,514' 10-%" 600 sx 6,700'(Est) 6-%" DV Collar , 8,514' 8,516' 13-3/8" ,� 3I i' 6'/" 24 P-110 5.921" 8,516' 9,380' 600 sx 9,100'(Est) 2,017' 4" Liner 9.5 L-80 3.468" 9,036' 11,403' 5-%" 242 sx 9,544'CBL Tubing Cplg OD 3%z",EVE 8RD 19.3 I L-80 I 2.992" I 0' I 9,030' 1111111511MMINSO 4.500" CBL EST 1 6,700' r"i`, ' r `' 's'd JEWELRY DETAIL No. Depth I ID OD Item • •+ 1 20' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 4 Ci' 2 21' 2.992" 3.500" Pups,3-1/2"8RD ,' '` ,4 3 4,108' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) @ r, 4 6,993' _ 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2(Live Valve) 5 8,500' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD Extra(Dummy) 6 8,953' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice) 5 C i 7 9,007' 3.000" 5.500" Olgoonik AS1-X Mechanical Packer(24#-32#) 8 9,020' 2.813" 4.438" X-Nipple 9 9,030' 2.992" 4.438" WL Entry Guide 10 ? - - Fish(J-lugs and packer rubbers from 6-5/8"24#AS1-X) LIN 5/23/14 6 1 Short Marker Joints @ 10,589'-10,599'MD @ 10,841'-10,851'MD I I I @ 10,973'-10,992'MD 7 Capillary String Installed 6/17/14 8 3/8" 2205 Stainless Steel(10,300'spool) Top Bottom MD 0' 9,025' TOL 9 TVD 0' 9,025' 9,036' CBL EST., 4', Is ,,,,,, PERFORATION DETAIL 9,100' Date Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) SPF Ft Phase Comments 9,3/8 P.; 9 ,380' 5/31/14 H-5 10,910' 10,950' 10,484' 10,510' 6 40 60 2.5"Connex - 'j 5/31/14 H-7 _ 11,050' 11,070' 10,575' 10,588' 6 20 60 2.5"Connex CBL TOC', 44 9,544' fe N GLV Port Temp @ MrkJtt' # Size Depth TCF PSC PSO PTRO Description 4, ,t II 20 131 0.856 1692 2000 2130 IPOR-1/IPOC-1/PPOR-1 a` - 20 167 0.799 1662 1861 2095 IPOR-1/IPOC-1/PPOR-1 ?` 20 191 0.765 1552 1747 1995 IPOR-1/IPOC-1/PPOR-1 Mrk Jt 1 :,,. H-5 1 Mrk Jt t 10 ^ 11-7 4" ,, �y •,.- '" 11,403' ^.G, r e.1,, Openhole '' ''',d 11,525' TD=11,525' PBTD=11,276' MAX HOLE ANGLE=55°@ 10,554' SCU 44B-33 Actual Schematic 6-17-14 Undated by STP 7/16/14 Hilcorp Alaska, LLC Swanson River Field SCU 44B-33 FINAL WELL REPORT DML LOGGING DATA Provided by: Approved by: John Serbeck Compiled by: Larry Resch Jim Foradas Distribution: 6/12/2014 TD Date: May 10, 2014 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Well Synopsis: ................................................................................................................................3 2.4 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithostratigraphy .............................................................................................................................6 3.2 Lithologic Details.............................................................................................................................7 3.3 Connection Gases ........................................................................................................................11 3.4 Trip Gases ....................................................................................................................................11 3.5 Sampling Program / Sample Dispatch..........................................................................................12 4 DRILLING DATA..................................................................................................................................13 4.1 Directional Survey Data................................................................................................................13 4.2 Bit Record.....................................................................................................................................17 4.3 Mud Record ..................................................................................................................................18 5 SHOW REPORTS ...............................................................................................................................19 6 DAILY REPORTS ................................................................................................................................20 Enclosures: 2” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD SCU 44B-33 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Mudlogging Unit Computer System Canrig: 3 HP Compaq Workstations (DML, RigWatch, and Sample Catcher) 0 Ditch Gas Canrig: (2) QGM Gas Traps (with High RPM Electric-Powered Agitators) Canrig: E-Series FID THA Analysis and Chromatography. 0 Pason EDR All Drilling Parameters 0 Block Height / Depth Pason WITS Feed 0 Hookload / WOB Pason WITS Feed 0 RPM Pason WITS Feed 0 Torque Pason WITS Feed 0 Return Flow Pason WITS Feed 0 Pit Volumes Pason WITS Feed 0 Mud Gain/Loss Pason WITS Feed 0 Pump Pressure Pason WITS Feed 0 Pump Strokes Pason WITS Feed 0 Rate of Penetration Calculated from Block Position tracking 0 Mud Flow In Calculated from Pump Output/Rate tracking 0 1.2 Crew Unit Number : ML030 Unit Type : Arctic Steel Skid Unit Mudloggers Years* Days*2 Sample Catchers Years Days*2 Technician Days Larry Resch 13 11 Fred Spiers 8 9 Jim Foradas 8 17 Ben Calo 1 9 James Adams 2 7 *1 Years experience as Mudlogger. *2 Days at well site. SCU 44B-33 3 2 WELL DETAILS 2.1 Well Summary Well: SCU 44B-33 API Number: 50-133-10170-01-00 Field: Swanson River Field Surface Co-Ordinates: 660’ FSL, 627’ FWL, Sec 34, T7N, R9W SM Borough: Kenai Borough, AK Primary Target: Depth: Hemlock H7, H10 10967’MD/ - 1010427’SSTVD State: Alaska TD Depth: 11525’MD / 10903’TVD Rig Name / Type: Saxon 169/Double Suspension Date: n/a Primary Target: Hemlock Sands Permit to Drill: 214054 Spud Date: 05/03/2014 Ground Elevation: 133.00’ AMSL Completion Status: Run 4” Liner RKB Elevation: 151.00’ AMSL Classification: Development Oil Secondary Target: Depth: Tyonek G2; Hemlock H1 10430’MD; 10564’MD TD Formation: Hemlock TD Date: 05/10/2014 Days Drilling: 8 Days Testing: n/a 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Wt (ppg) Dev. (o inc) Casing/ Liner MD (ft) TVDSS (ft) FIT (ppg) 5 5/8” 11,525 10,902 L. Hemlock 10.5 43.44 4.0” 11403 10815 12.0 2.3 Well Synopsis: SCU 44B-33 is a development oil well planned sidetrack to be drilled in a Westerly direction from the parent well SCU 14-34. A 2100’ x 5-1/8”” open hole section is planned. Spudded on May 3, 2014, SCU 44B-33 was drilled from the window cut at 9392’MD to a total depth of 11525’MD/ 10903’TVD. No issues while drilling were experienced with the possible exception of differential sticking in the lowest 300 ft of the hole. Additionally, the well began to flow fresh water at approximately 10100’MD with mud weight of 9.55 ppg. Mud weight was eventually increased to 10.55 ppg as the well continued to flow. Total depth of 11525 ft was reached on May 10, 2014. Differential sticking and flowing of the well continued to present problems during the trip out of hole after TD, and during an attempt to trip into the hole for a MAD pass after TD which resulted in sticking within 100’ of the window. A typical 4” liner completion is planned for this well. SCU 44B-33 4 2.4 Daily Activity Summary May 2, 2014: Completed rig up of Canrig DML logging unit and gas sampling system. The rig continued POOH; L/D scraper assembly; R/U E-line, RIH w/ gamma, tagged at 10,250'; RIH w/ CIBP, set at 9,390'. M/U Whipstock assembly and RIH T/ 9,342'; CBU and R/U E-line to orient; currently orienting whipstock. May 3, 2014: Continue RIH w/ E-line to orient whipstock. RIH w/ DP and tagged CIBP at 9,397'. RIH w/ E-line and oriented whipstock, set at 9,380'; displaced well from produced water to 9.5 ppg 6% KCL/PHPA mud; Began milling window, Top at 9,380', bottom at 9,392'; pumped hi-vis sweep at 9,388' observing 20% increase in cuttings; pumped hi-vis sweep at 9,398', observing 10% increase in cuttings, mostly sand w/ some fine metal; collected 128 lbs. of metal cuttings at shakers; continued drilling ahead to 9,403'; currently pumping hi-vis sweep at 9402’. May 4, 2014: Circulated out hi-vis sweep, observing 10% increase in cuttings, mostly fine sand with no visible metal; conducted FIT to 12.0 ppg EMW; pumped dry job and POOH from 9,360' to surface. P/U new mill bit and 33 singles; RIH washing and reaming from 9,380' to 9,407'; pumped hi-vis sweep at 9,377', observing no increase in cuttings; pumped dry job and POOH; currently POOH at 8,502’ May 5, 2014: Continued POOH from 8502’ to surface; L/D milling assembly; P/U directional BHA (BHA#4); RIH to 9,404'; R/U wireline with side entry sub and test; Drill ahead from 9,407'; currently drilling at 9413’. May 6, 2014: Continued drilling ahead from 9417', rigging down wireline in the process; currently drilling ahead at 9694’. May 7, 2014: Continued drilling ahead from 9694' to 9835' and observed the well to be flowing 1 bph; continued drilling ahead to 10,088'; observed well flowing at 6.2 bph with connection gas at 485 units; decision was made to increase MW to 9.7+ ppg; continued drilling ahead to 10,212' and flow checked; flow at 8 bph and connection gas at 451 units; decision made to increase MW to 10.0 ppg while drilling ahead; last connection gas was 244 units, currently drilling at 10285’. May 8, 2014: Drilled from10,285' to10,338', flow checked well during connections; flow at 10 bph, increased MW to 10.1ppg; drilled to10,400' and flow reduced to 8.5 bph; began weight up to 10.3ppg, but decision was made to continue drilling ahead with current 10.2 ppg MW. Pumped 20bbl Hi-Vis sweep at 10,550' seeing 50% increase in cuttings; continued drilling to10,705'; tried to slide, but string began to differentially stick; pumped another 20 bbl Hi-Vis sweep with no increase in cuttings observed; drilled ahead to 10,802’; CBU; POOH to10,339' to wipe hole; RIH to10,802’; drilled ahead slowly; currently at 10812’. May 9, 2014: Continued drilling ahead from 10,812'; and checked flow at connection; flow continued to hold at 10bph; increased background LCM to 30ppb; checked flow at 11,387' and flow was 8bph; currently drilling ahead at 11,486’MD. SCU 44B-33 5 May 10, 2014: Drilled to TD at 11,525'; CBU (67 units); pumped a 20bbl hi-vis sweep seeing 10% increase in cuttings; spotted a 70bbl 50ppb pill with a MW of 10.5ppg and a 80 Vis on bottom; began POOH, pulling hard from 11,525' to 10,680 with 40-50K over; continued POOH to into the window; slipped and cut drill line while monitoring well, flow 7-8bph; decision made to RIH to bottom, weigh up, and spot another pill; RIH to bottom; weighed up to 10.55ppg MW; CBU (663units); dumped 40bbl fresh water from formation; began POOH; currently POOH at 2033’.. May 11, 2014: Finished TOOH, L/D BHA, Flow check while out of the hole was 6bph; M/U LWD assembly for Mad Pass and TIH to window; began seeing gas at possum belly when filling DP; decision made to CBU @ 7000'; Dumped 21 bbl H2O from formation, lowest weight was 8.9ppg and max gas was 690 units; continued RIH to window; CBU- dumped 100 bbl H2O from formation; lowest MW was 8.3 ppg and max gas was 640 units; TIH to 9584' and became stuck. Attempts to free stuck pipe included pumping a 20 bbl hi-vis 40ppb sweep, which resulted in a 25% increase in cuttings mostly tuffaceous siltstone (40%), tuffaceous sandstone (30%), and tuffaceous claystone (30%) with traces of coal (1-2%), and additives used for the sweep; we have been working stuck pipe since 5:30 PM. May 12, 2014: DP Freed up at 00:30, reciprocated pipe during CBU; which exhibited minor increase in cuttings composed of tuffaceous siltstone (40%), tuffaceous sandstone (30%), and coal (30%); pumped a 20 bbl Hi-Vis sweep while reciprocating, with no increase in cuttings. TOOH to 9523’; jarring down and back reaming to 9300'; performed derrick inspection; slip and cut drill line; Flow-checked well (4.8bph flow); decided to POOH; spotted 50bbl, 12.5ppg and 80 Vis pill at window; POOH 10 stands and flow-check (4.0 bph flow); POOH to above window; pumped a second similar pill chasing it with 61 bbl and pumping remaining (20 bbl) as a slug; flow-check (2.5 bph flow); POOH 10 stands and flow-check (well static); POOH to HWDP, flow-check (4.2 bph flow). Began testing BOP's and flow check (4.7 bph flow); currently testing BOP's. May 13, 2014: Finished testing BOP's, well flow avg. 4.5bph during tests; P/U BHA and TIH to 4800' and observed water at surface; TIH 9351'; circulated out 216bbls of H2O/Mud, mostly 8.4 ppg (800 mg/L Cl-) and 184units of gas; started taking back returns into the active at 10.2 ppg MW; started circulating and reaming to bottom at 9450'; currently reaming at 9497’ MD. May 14, 2014: Continued RIH, reaming to 10,300'; pumped 20bbl hi-vis sweep, observing 150% increase in cuttings (54u trip gas); RIH, reaming to bottom; pumped Hi-Vis sweep observing 30% increase in cuttings and barite and 11units gas; started logging while BROOH from bottom to window, which is currently in progress. May 15, 2014: Finished Logging to window; pulled up into the CSG; serviced rig; CBU with flow at 4.7bph; RIH to bottom on elevators rotate and pump through tight spot at 9775’ ; pumped a 20 bbl Hi-Vis sweep with CBU (maximum gas 1125 unit), observed no increase in cuttings ; spotted 100bbl 100ppb LCM pill on bottom; TOOH to 8613'; spotted 63bbl Hi-vis and barite pill (12.5 ppg); dropped rabbit; L/D 73 joints of 4" DP; TOOH, well flowing at 2.8bbls/hr. R/U Weatherford to run liner; RIH with Liner. May 16, 2014: Started RIH with 4” Liner; over torqued landing collar; waited on new collar to arrive from town; resumed RIH with 4" liner, well flowing at 4 bbls/hr; currently RIH at 8203’ MD with background gas beginning to increase steadily to present background level after filling pipe at 6803’ MD. May 17, 2014: Continued RIH with 4” Liner; landing at 11,403’; CBU returned 1162 units gas; R/U Cementers and pump cement; Canrig Logging Crew released and started DML Mudlogging Unit rig down. SCU 44B-33 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy All tops were provided by Hilcorp geologist John Serbeck. PROGNOSED OBSERVED FORMATION MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) KOP 9400 9400 -9249 9380 9379 -9228 Fault E 10401 10202 -10051 10342 10146 -9995 Tyonek G-2 10430 10221 -10070 10445 10208 -10057 Hemlock H1 10564 10310 -10159 10586 10291 -10140 Hemlock H4 10803 10468 -10317 10859 10452 -10301 Hemlock H7 10967 10578 -10427 11043 10570 -10419 Hemlock H10 11141 10694 -10543 11239 10701 -10550 TD 11525 10903 -10752 11526 10903 -10752 SCU 44B-33 7 3.2 Lithologic Details Tuffaceous Claystone, Tuffaceous Siltstone (9392'-9420') = medium light gray to light gray; soft; mushy, pasty; malleable, pulverulent; no definable fracture, cuttings habit, bedding or structure; slightly to very arenaceous in part with varying amounts of well rounded quartz sand; noncalcareous; trace carbonaceous detrital fragments, occasional thinly bedded coal; NSOFC. Tuffaceous Sandstone (9420'-9540') = light gray to very light gray, becoming white to grayish white; lower fine to upper very fine grain; angular to subangular, subrounded common; prismoidal to subprismoidal, subdiscoidal in part; well sorted; poorly consolidated; soft, crumbly in part; noncalcareous; varies from grain supported to matrix supported with abundant translucent, transparent quartz well disseminated within a pulverulent ash matrix; very fine glass shards common; trace biotite; note trace to common bitumen/ dead oil stain; NFOC. Tuffaceous Siltstone, Tuffaceous Sandstone (9540'-9600') = olive gray to gray with lighter hues where arenaceous; curdy; crumbly to elastic depending on clay content; irregular fracture; tabular to wedge like cuttings habit with some butter curl like clayier cuttings; dull earthy to slightly waxy luster; smooth to granular textures; thin to laminar structure; intergrading to claystone and sandstone as described above; interbedded with thin lenses of carbonaceous shale and coal in places; NSOFC. Tuffaceous Siltstone, Tuffaceous Claystone (9600'-9660') = olive gray to gray with white and reddish brown hues; curdy; crumbly to malleable depending on clay content; irregular fracture; tabular to wedge like cuttings habit; dull earthy to slightly waxy luster; smooth to granular textures; thin to laminar structure; arenaceous in places and intergrading to tuffaceous sandstone with depth; interbedded with thin coal and carbonaceous shale beds in places. Tuffaceous Sandstone, Conglomerate (9660'-9720') = light gray with greenish and pale orange to white hues; lower very fine to very coarse with fragments of larger clasts; poor to well sorted with medium size grains most common; angular to rounded; very low to moderate sphericity; common mechanical abrasion features; grain supported; some silty tuffaceous matrix; composed of volcanic glass with quartz and feldsic rock fragments; common greenstone, quartzite and dark lithics, some cherty; trace k-feldspar and ash; coarsening down, terminating in thin slightly off gassing coal; NSOFC Tuffaceous Claystone (9720'-9780') = light gray with slight light bluish gray hues, light gray with olive to pale yellowish brown hues; soft; crumbly, pulverulent; earthy in part; nodular to slightly tabular cuttings with well rounded edges; dull to slightly sparkly luster when silty/ sandy, subwaxy in part; noncalcareous; hydrophilic; with shaley coals interbedded. Tuffaceous Sandstone, Conglomeratic Sand (9780'-9930') = grayish white to white, very light gray with varying degrees of light bluish gray and pale yellowish brown hues; dominantly lower fine grain with upper very fine, upper fine grain common; subangular to angular, occasionally subrounded; subprismoidal to prismoidal, rarely subdiscoidal; moderate to well sorted; friable to poorly consolidated within pulverulent ashy/ argillaceous matrix; varies from grain supported to matrix supported; a sublithic arenite in part; noncalcareous; no visible porosity; translucent, milky white, transparent quartz grains dominate with locally abundant glass shards and volcanic glass; reddish orange mafic minerals common; trace biotite; note common organics, carbonaceous detritus, bitumen dead oil stain; NFOC. SCU 44B-33 8 Tuffaceous Sandstone, Conglomeratic Sand, Sand (9930'-9950') = note loose, disaggregated sand increasing from 10 to 40% through interval; poorly consolidate sandstone is white to grayish white, very light gray, pale yellowish brown; lower fine to upper very fine grain; subangular to subrounded; subprismoidal to occasionally subdiscoidal; moderately well sorted; noncalcareous; quartz dominant with dark gray to grayish black greenstone, occasional reddish orange mafic minerals; varies from a matrix supported to very ashy sublithic arenite matrix/ ash component is very soft, pulverulent; note occasional lower coarse well rounded subdiscoidal intact pebbles and similar sized angular pebble fragments; NSOFC. Tuffaceous Sandstone, Conglomeratic Sand (10050'-10170') = light gray with light brown, pale greens and brownish hues; predominantly upper very fine to upper medium grained ranging to very coarse; grain supported with ample ash and tuff matrix; fair to well sorted; subangular to round; soft to easily friable with some harder; mostly volcanics with quartz; laminae of carbonaceous and biotite fines; bedded with thin lenses of tuff, ash, coal and conglomerates making up < 10% of sample; a few darker brown gray sandstone cuttings were observed to exhibit dull yellow fluorescence; no cut; slight odor, yellow fluorescence, yellow cut fluorescence and instant milk cut when analyzed in a sample with drill mud; note that at no time was there more than 5% sample fluorescence overall. Coal (10190'-10210') = black to dark gray with brownish hues; lignitic; stiff and brittle to crumbly; irregular planar splintery to subconchoidal fracture; elongated tabular to wedge like cuttings habit; dull to resinous luster; matte to mottled texture; thin laminar structure; occurring in thin beds with tuffaceous sandstone, brown ash, carbonaceous shale and finer tuffaceous rocks; no off gassing observed in cuttings. Tuffaceous Claystone, Tuffaceous Sandstone (10200'-10290') = clays gray to brownish gray; curdy to mushy; crumbly to pulverulent; irregular fracture; tabular to nodular cuttings; dull waxy luster; smooth to gritty; common ash. Tuffaceous Claystone, Tuffaceous Siltstone (10290'-10380') = light to medium gray to brownish gray; mushy to curdy; crumbly to pulverulent; irregular blocky fracture; tabular to nodular cuttings habit; dull earthy luster; smooth to granular texture; some laminae; generally thin bedded and intergrading with tuffaceous sandstone; interbedded with thin coals and carbonaceous shale; coals are black to dark brown, tough to crunchy, with planar to subconchoidal fracture, elongated wedge like cuttings, matte to resinous luster, matte texture and fine laminae; coal cuttings slightly off gassing; tuffaceous sandstones in this zone are similar to those described above; NSOFC. Carbonaceous Shale, Shaley Coal (10380'-10450') = note overall change of sample character with decreasing grayish colors and increased moderate to pale yellowish brown earthy claystone; dark gray to grayish black dull luster, occasional black vitreous luster carbonaceous shale/ shaley coal, coal; firm to moderately hard; irregular to planar, splintery fracture; occasional bird eye fracture in better developed coal; tabular to wedge like cuttings; rare to trace very fine outgassing. Tuffaceous Sandstone, Conglomeratic Sand, Sand (10450'-10540') = interval varies from 10 to 40% loose/ disaggregate sand; poorly consolidated sandstone is grayish white to white, very light gray; upper very fine to lower fine grain; subrounded to subangular; subdiscoidal to subprismoidal; well sorted; noncalcareous; very soft, brittle; quartz sand dominant with abundant volcanic glass clasts, shards, mafic minerals poorly consolidated in a pulverulent weathered tuff/ash matrix; sublithic arenite to 'ash stone' in part note lower coarse well rounded intact pebbles and pebble fragments with high impact fracture; TRACE YELLOWISH BROWN OIL STAIN; TRACE FREE OIL IN PROCESSED SAMPLES; NOTE FLUID REMAINING IN PROCESSED SAMPLES FLUORESCES YELLOWISH WHITE; VERY SLIGHT HYDROCARBON ODOR; IMMEDIATE BURST LIGHT MILKY TO YELLOW SOLVENT REACTION; CONCENTRATED MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. SCU 44B-33 9 Tuffaceous Sandstone, Sand (10540'-10730') = 30 to 90% loose/ disaggregated sand; tuffaceous sandstone is white to grayish white, very light gray in part with occasional slight pale yellowish brown hues; upper very fine to lower fine grain, upper fine grain and beyond in places; subangular, occasionally angular, trace subrounded; subprismoidal to subdiscoidal; moderate to locally well sorted; noncalcareous; poorly consolidated with quartz and minor secondary dark gray to grayish black lithics, volcanic glass clasts, note local conglomeratic sand, pebbles occasional pebble fragments; note carbonaceous shale/ shaley coal at 10650'; TRACE MEDIUM BROWN TO YELLOWISH BROWN STAIN WITH SLIGHT REDDISH HUE AT TOP OF INTERVAL, DIMINISHING WITH DEPTH; NO VISIBLE OIL BLEBS; NO ODOR; 40 TO 100% BRIGHT YELLOW SAMPLE FLUORESCENCE; SOLVENT PRODUCES INSTANT MILKY WHITE FLUORESCENT BURST WITH IMMEDIATE MILKY STREAMERS THAT DISSIPATE QUICKLY; MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. Tuffaceous Sandstone, Sand (10730'-10810') = light gray with pale brown and gray white hues; upper very fine grained to upper fine grained; well to very well sorted; subrounded to round; moderate to very high sphericity; common polish; soft to unconsolidated; ash matrix supported with some harder grain supported cuttings; interbedded with tuffaceous claystone, thin carbonaceous shale and ash; 40 to 90% DULL TO BRIGHT YELLOW FLUORESCENCE; INSTANT DULL TO STRONG MILK CUT AND YELLOW CUT, STRONGER RESIDUAL CUT; SHOW QUALITY DECREASES WITH DEPTH. Tuffaceous Sandstone, Sand (10810'-10900') = light gray with pale brown and gray white hues; upper very fine grained to upper coarse with some coarser; fair to well sorted; angular to well rounded; low to high sphericity; common mechanical abrasion features; unconsolidated to soft; grain supported with ash matrix; interbedded with thin coal, carbonaceous shale and tuffaceous claystone; SAMPLE FLUORESCENCE 20 TO 60%, INSTANT TO SLOW PALE TO BRIGHT MILK CUT; SOME YELLOW TO BROWN CUT/RESIDUAL CUT, RING, FLUORESCENCE. Conglomeratic Sand (10900'-11020') = overall sample color is white to grayish white to very light gray, medium to lower coarse grain; subangular to subrounded, often angular, trace well rounded; subprismoidal to subdiscoidal, prismoidal common; moderate sorting; note minor poorly consolidated upper very fine to fine grain silt/ sand grains well disseminated and entrained in very pulverulent well weathered tuff/ ash matrix; note white to grayish white very soft ashy nodules; predominantly milky to grayish white and translucent matte quartz with abundant transparent volcanic glass clasts and very fine glass shards; very minor secondary grayish black to black lithics, greenstone, orange mafic minerals; note clasts containing biotite and loose biotite flakes; NO STAIN OR HYDROCARBON ODOR; INTERVAL VARIES 40 TO 100% YELLOW WHITE TO BRIGHT YELLOW FLUORESCENCE; NOTE GOLD TO ORANGE TO DULL ORANGE BARACARB MINERAL FLUORESCENCE; IMMEDIATE BRIGHTENING WITH FLUORESCENT WHITE TO MILKY BURST SOLVENT REACTION AND INSTANT WISPY MILKY STREAM CUT WHICH DISSIPATES RAPIDLY; NOTE OCCASIONAL SLOWER MILKY TO LIGHT MILKY STREAMING CUT; BRIGHT WHITE TO MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. Carbonaceous Shale, Coal (11020'-11040') = dark gray to grayish black, black, brownish black; firm to moderately hard; crunchy, brittle, dense in part; planar to splintery fracture, hackly; tabular to scaly cuttings habit; dull luster; subfissile; none to rare visible out gassing along laminar planes; trace pyrite. SCU 44B-33 10 Tuffaceous Sandstone, Conglomeratic Sand, Sand (11040'-11190') = interval is dominated by a series of upward fining sequences with abundant upper medium to lower coarse subangular conglomeratic sand and pebble fragments overlain by upper very fine to fine loose/disaggregated sand, tuffaceous/ ashy/ argillaceous sandstone with occasional ash nodules, tuffaceous claystone/ siltstone; quartz dominant with minor black to grayish black lithic and mafic minerals; NO STAIN OR ODOR; 30 TO 90% YELLOW (UPPER) TO YELLOW ORANGE (LOWER) FLUORESCENCE; SOLVENT PRODUCES AN IMMEDIATE BRIGHTENING WITH INSTANT WHITE TO MILKY WHITE BURST WITH OCCASIONAL RAPIDLY DISPERSING WISPY STREAMING CUT; BRIGHT WELL DEFINED MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. Tuffaceous Claystone (11190'-11250') = light to medium gray with brownish hues; curdy to mushy; crumbly to pulverulent; irregular blocky fracture; nodular cuttings habit; dull to greasy luster; silty to granular texture; increasingly gritty with depth intergrading to siltstone; thin to thick structure; interbedded with thin coals and carbonaceous rocks. Tuffaceous Sandstone, Sand (11250'-11340') = light gray with white and pale brown hues; upper very fine to upper medium grained with coarser grains; poor to well sorted; subangular to subrounded; low to high sphericity; common signs of mechanical abrasion; ash matrix supported to grain supported where harder; generally soft to easily friable and intergrading to finer tuffaceous rocks in places; WEAK YELLOW ORANGE FLUORESCENCE 5-60%; FEINT ODOR; TRACE STAIN; SLOW MILK CUT; DULL YELLOW TO GOLD CUT; SOME STRONG RESIDUAL MILK CUT AND BRIGHT YELLOW RESIDUAL FLUORESCENCE; COMMON RING CUT TO 11310'; show zone ends in thin coal and carbonaceous shale beds between 11330'-11340'. Tuffaceous Sandstone, Conglomeratic Sand (11350'-11400') = light gray with white and pale brown hues; lower fine to very coarse; very poor to fair sorted with angular to subrounded clasts; low to moderate sphericity; common abrasion features; soft; ash matrix supported; coarsening down; interbedded with thin carbonaceous shale; WEAK SLOW MILKY CUT WITH WEAK YELLOW GOLD CUT FLUORESCENCE ABOVE 11380'; NO RESIDUAL CUT. Tuffaceous Siltstone, Tuffaceous Claystone (11400'-11525') = medium gray with lighter and darker brownish gray hues; clotty to mushy; crumbly to malleable; nodular to tabular cuttings habit with dull to greasy luster; gritty to granular to colloidal texture; common darker laminae in places; mostly thin structure; interbedded with thin coals sand, and carbonaceous shale; intergrades to matrix supported tuffaceous sandstone in places; NSOFC. SCU 44B-33 11 3.3 Connection Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) Measured Depth (feet) Subsea Total Vertical Depth (feet) Gas over background (units) 9714.20 23 10657.29 122 9777.48 6 10720.06 260 9840.25 13 10782.81 136 9902.96 19 10846.77 208 9965.68 30 10909.49 231 10028.86 53 10973.07 123 10092.09 485 11035.90 187 10154.68 464 11098.48 141 10217.37 451 11161.68 120 10279.62 244 11224.34 141 10343.05 583 11288.21 105 10405.68 546 11351.50 77 10468.25 204 11413.76 99 10531.51 168 11476.08 150 10594.75 150 3.4 Trip Gases 50 units = 1% Methane Equivalent Measured Depth (feet) Trip to (feet) Maximum Gas (Units) Pumps Off Time (hours) 0 9403 3 17.0 0 9407 62 17.5 10802 10339 507 1.3 11525 9208 663 7.5 9208 11450 93 1.7 11450 0 625 12.7 0 9627 690 10.6 9627 0 334 6.0 0 11525 184 13.5 11525 9328 12 0.25 9328 11525 1125 0.05 0 11525 6 13.25 0 11403 1342 24.5+- 11420 11420 1162 0 SCU 44B-33 12 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency* Interval Dispatched to A, B Washed and dried reference samples 30 ft 10 ft 9380 ft – 10410 ft 10410 ft – 11525 ft Debra Oudean Hilcorp Alaska LLC 3800 Centerpoint Drive Suite #100 Anchorage AK 99503 (907) 777-8337 C Wet unprocessed Reference samples for QC analysis 10 ft 10410 ft – 11525 ft Canrig Drilling Technology 1615 Jefferson Island Road New Iberia LA 70560 Attn.: Geoff Davison (337) 380-5298 D Drilling Mud Samples Reference samples for QC analysis 50 ft 10410 ft – 11525 ft Canrig Drilling Technology 1615 Jefferson Island Road New Iberia LA 70560 Attn.: Geoff Davison (337) 380-5298  Sample frequency may be locally altered according to drill rate constraints and zones of interest. SCU 44B-33 13 4 DRILLING DATA 4.1 Directional Survey Data Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 17.77 0.00 0.00 17.77 0.00 0.00 0.00 0.00 100.67 0.12 121.47 100.67 -0.05 0.07 -0.06 0.14 200.67 0.18 131.28 200.67 -0.20 0.28 -0.23 0.07 300.67 0.21 159.32 300.67 -0.48 0.46 -0.35 0.10 400.67 0.19 150.18 400.67 -0.79 0.61 -0.43 0.04 500.67 0.22 150.08 500.67 -1.10 0.79 -0.53 0.03 600.67 0.25 161.29 600.67 -1.48 0.96 -0.61 0.05 700.67 0.18 162.77 700.67 -1.83 1.07 -0.65 0.07 800.67 0.07 175.66 800.67 -2.04 1.12 -0.66 0.11 900.67 0.06 274.86 900.67 -2.10 1.08 -0.60 0.10 1000.67 0.09 262.50 1000.67 -2.11 0.95 -0.47 0.03 1100.67 0.16 271.11 1100.67 -2.11 0.73 -0.26 0.07 1200.67 0.15 277.19 1200.67 -2.10 0.46 0.00 0.02 1300.67 0.11 272.76 1300.67 -2.07 0.23 0.22 0.04 1400.67 0.19 255.22 1400.66 -2.11 -0.02 0.48 0.09 1500.67 0.15 243.31 1500.66 -2.21 -0.30 0.77 0.05 1600.67 0.16 249.15 1600.66 -2.32 -0.55 1.04 0.02 1700.67 0.19 247.83 1700.66 -2.43 -0.83 1.34 0.03 1800.67 0.23 244.50 1800.66 -2.58 -1.17 1.70 0.04 1900.67 0.23 243.15 1900.66 -2.76 -1.53 2.09 0.01 2000.67 0.23 239.02 2000.66 -2.95 -1.88 2.47 0.02 2100.67 0.20 238.08 2100.66 -3.15 -2.20 2.83 0.03 2200.67 0.18 236.82 2200.66 -3.33 -2.48 3.14 0.02 2300.67 0.17 245.56 2300.66 -3.48 -2.74 3.43 0.03 2400.67 0.07 304.62 2400.66 -3.50 -2.93 3.62 0.15 2500.67 0.09 279.38 2500.66 -3.45 -3.06 3.73 0.04 2600.67 0.08 268.63 2600.66 -3.44 -3.21 3.87 0.02 2700.67 0.11 296.51 2700.66 -3.40 -3.36 4.01 0.05 2800.67 0.10 316.54 2800.66 -3.30 -3.51 4.13 0.04 2900.67 0.13 318.89 2900.66 -3.15 -3.64 4.23 0.03 3000.67 0.09 270.02 3000.66 -3.06 -3.79 4.36 0.10 3100.67 0.28 208.90 3100.66 -3.28 -3.99 4.60 0.25 3200.67 0.57 201.30 3200.66 -3.95 -4.29 5.04 0.29 3300.67 0.78 202.05 3300.65 -5.05 -4.73 5.70 0.21 3400.67 0.83 201.71 3400.64 -6.35 -5.25 6.49 0.05 3500.67 0.59 203.24 3500.63 -7.50 -5.72 7.20 0.24 3600.67 0.48 214.21 3600.63 -8.32 -6.16 7.80 0.15 3700.67 0.45 218.64 3700.62 -8.97 -6.64 8.42 0.05 3800.67 0.38 222.46 3800.62 -9.52 -7.11 8.99 0.08 3900.67 0.30 246.73 3900.62 -9.87 -7.57 9.52 0.16 SCU 44B-33 14 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 4000.67 0.38 281.91 4000.62 -9.90 -8.14 10.08 0.22 4100.67 0.32 318.08 4100.61 -9.63 -8.65 10.52 0.22 4200.67 0.36 330.45 4200.61 -9.15 -8.99 10.75 0.08 4300.67 0.38 340.04 4300.61 -8.56 -9.26 10.88 0.06 4400.67 0.41 332.50 4400.61 -7.93 -9.54 11.02 0.06 4500.67 0.43 337.47 4500.61 -7.27 -9.85 11.18 0.04 4600.67 0.42 337.99 4600.60 -6.58 -10.13 11.31 0.01 4700.67 0.31 334.83 4700.60 -6.00 -10.38 11.43 0.11 4800.67 0.30 349.00 4800.60 -5.50 -10.55 11.48 0.08 4900.67 0.36 358.87 4900.60 -4.92 -10.60 11.41 0.08 5000.67 0.51 25.90 5000.60 -4.21 -10.41 11.08 0.25 5100.67 0.70 24.78 5100.59 -3.26 -9.96 10.43 0.19 5200.67 0.74 25.06 5200.58 -2.12 -9.43 9.67 0.04 5300.67 0.78 26.67 5300.57 -0.92 -8.85 8.85 0.05 5400.67 0.81 24.46 5400.56 0.33 -8.26 7.99 0.04 5500.67 0.48 15.99 5500.56 1.38 -7.85 7.37 0.34 5600.67 0.36 7.33 5600.55 2.09 -7.69 7.06 0.14 5700.67 0.28 323.03 5700.55 2.60 -7.80 7.06 0.25 5800.67 0.32 285.36 5800.55 2.87 -8.22 7.41 0.20 5900.67 0.66 256.49 5900.55 2.80 -9.04 8.23 0.41 6000.67 0.77 257.11 6000.54 2.52 -10.26 9.48 0.11 6100.67 0.78 258.33 6100.53 2.23 -11.58 10.83 0.02 6200.67 0.78 255.35 6200.52 1.92 -12.91 12.19 0.04 6300.67 0.85 256.08 6300.51 1.57 -14.28 13.61 0.07 6400.67 0.77 254.30 6400.50 1.21 -15.65 15.02 0.08 6500.67 0.77 248.15 6500.49 0.78 -16.92 16.36 0.08 6600.67 0.86 230.42 6600.48 0.05 -18.12 17.69 0.27 6700.67 0.93 230.75 6700.47 -0.94 -19.33 19.08 0.07 6800.67 1.04 227.52 6800.46 -2.07 -20.63 20.59 0.12 6900.67 1.06 225.48 6900.44 -3.33 -21.96 22.16 0.04 7000.67 0.98 224.03 7000.42 -4.59 -23.21 23.66 0.08 7100.67 0.79 223.91 7100.41 -5.70 -24.28 24.94 0.19 7200.67 0.47 213.19 7200.40 -6.54 -24.99 25.81 0.34 7300.67 0.45 209.44 7300.40 -7.23 -25.40 26.36 0.04 7400.67 0.29 224.25 7400.40 -7.75 -25.77 26.84 0.19 7500.67 0.26 208.39 7500.40 -8.13 -26.06 27.20 0.08 7600.67 0.30 170.22 7600.40 -8.59 -26.12 27.36 0.19 7700.67 0.44 162.87 7700.40 -9.21 -25.96 27.34 0.15 7800.67 0.66 156.68 7800.39 -10.11 -25.62 27.20 0.23 7900.67 0.81 159.78 7900.38 -11.30 -25.15 26.99 0.16 8000.67 1.00 156.91 8000.37 -12.77 -24.56 26.74 0.20 SCU 44B-33 15 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 8100.67 1.13 162.72 8100.35 -14.51 -23.93 26.49 0.17 8200.67 0.99 165.90 8200.33 -16.29 -23.43 26.38 0.15 8300.67 0.88 161.13 8300.32 -17.86 -22.97 26.27 0.13 8400.67 0.76 165.66 8400.31 -19.23 -22.55 26.16 0.14 8500.67 0.49 157.38 8500.31 -20.26 -22.23 26.07 0.28 8600.67 0.61 186.55 8600.30 -21.19 -22.12 26.16 0.30 8700.67 0.84 173.47 8700.29 -22.44 -22.10 26.41 0.28 8800.67 0.33 200.19 8800.29 -23.44 -22.12 26.64 0.57 8900.67 0.29 199.82 8900.29 -23.95 -22.30 26.93 0.04 9000.67 0.20 314.38 9000.29 -24.07 -22.51 27.16 0.42 9100.67 0.03 207.74 9100.29 -23.97 -22.65 27.28 0.21 9200.67 0.58 41.07 9200.28 -23.61 -22.33 26.89 0.61 9300.67 0.59 61.18 9300.28 -22.98 -21.54 25.99 0.20 9380.00 0.39 310.51 9379.61 -22.61 -21.39 25.76 1.03 9411.85 2.99 283.19 9411.44 -22.35 -22.28 26.57 8.32 9453.48 7.89 281.49 9452.87 -21.53 -26.14 30.16 11.78 9483.21 11.07 279.88 9482.19 -20.63 -30.95 34.67 10.73 9516.32 13.02 280.86 9514.57 -19.38 -37.75 41.04 5.92 9547.31 13.15 269.62 9544.76 -18.75 -44.70 47.69 8.21 9578.67 14.20 254.19 9575.24 -19.82 -51.98 55.02 12.06 9609.37 16.36 250.69 9604.86 -22.28 -59.68 63.08 7.65 9639.41 16.46 248.64 9633.67 -25.23 -67.64 71.48 1.96 9672.98 18.48 253.39 9665.69 -28.48 -77.17 81.49 7.36 9708.50 20.57 254.41 9699.17 -31.77 -88.57 93.33 5.96 9736.45 22.85 255.18 9725.13 -34.48 -98.55 103.66 8.22 9768.48 25.64 254.55 9754.34 -37.91 -111.24 116.80 8.75 9799.50 29.50 254.52 9781.83 -41.74 -125.08 131.13 12.44 9831.68 33.13 256.04 9809.32 -45.98 -141.25 147.84 11.54 9862.95 36.00 256.13 9835.07 -50.24 -158.47 165.57 9.18 9894.76 38.68 256.42 9860.35 -54.82 -177.21 184.86 8.44 9926.53 41.36 254.84 9884.68 -59.90 -197.00 205.27 9.02 9958.24 44.05 254.24 9907.98 -65.63 -217.72 226.75 8.58 9988.19 46.66 255.40 9929.03 -71.21 -238.29 248.03 9.14 10020.71 49.58 256.95 9950.73 -76.98 -261.80 272.23 9.65 10050.91 51.66 257.03 9969.89 -82.24 -284.54 295.57 6.89 10085.50 53.03 256.70 9991.03 -88.46 -311.21 322.95 4.02 10112.69 52.88 256.22 10007.41 -93.55 -332.31 344.65 1.49 10177.40 52.74 256.50 10046.52 -105.70 -382.40 396.19 0.41 10238.80 51.96 255.86 10084.03 -117.31 -429.61 444.79 1.51 10302.84 53.53 257.82 10122.79 -128.91 -479.24 495.75 3.46 10365.49 53.15 257.57 10160.20 -139.62 -528.34 546.01 0.69 SCU 44B-33 16 Surveys (Continued) Measured Depth (ft) Inc. (o) Azi. (o) True Vertical Depth (ft) Northing (ft) Easting (ft) Vertical Section (ft) Dogleg Rate (o/100ft) 10427.13 52.28 257.71 10197.54 -150.12 -576.25 595.05 1.42 10491.15 54.37 258.68 10235.78 -160.62 -626.50 646.39 3.48 10553.74 54.56 258.65 10272.15 -170.63 -676.44 697.31 0.31 10616.39 54.26 257.79 10308.62 -181.03 -726.32 748.26 1.21 10678.88 54.15 258.31 10345.17 -191.52 -775.90 798.94 0.70 10741.31 53.77 259.13 10381.90 -201.40 -825.41 849.41 1.23 10806.56 53.88 258.69 10420.42 -211.53 -877.09 902.07 0.57 10839.26 52.47 258.58 10440.01 -216.69 -902.76 928.24 4.31 10868.57 51.08 259.74 10458.15 -221.02 -925.37 951.25 5.68 10900.16 50.34 260.09 10478.15 -225.30 -949.44 975.68 2.49 10931.52 50.19 259.25 10498.20 -229.63 -973.16 999.78 2.11 10994.30 49.66 259.65 10538.62 -238.42 -1020.39 1047.79 0.97 11058.96 49.02 259.40 10580.75 -247.34 -1068.62 1096.81 1.03 11121.39 48.50 259.74 10621.90 -255.84 -1114.79 1143.73 0.93 11184.40 47.65 259.09 10664.00 -264.45 -1160.87 1190.58 1.55 11247.57 46.76 259.14 10706.92 -273.20 -1206.39 1236.92 1.41 11310.44 46.36 258.85 10750.15 -281.92 -1251.20 1282.56 0.71 11372.96 45.45 258.33 10793.65 -290.80 -1295.22 1327.45 1.58 11435.07 44.17 258.87 10837.71 -299.45 -1338.13 1371.22 2.16 11484.98 43.44 258.69 10873.73 -306.17 -1372.01 1405.75 1.48 p. 11525.00 43.44 258.69 p. 10902.79 -311.57 -1398.99 1433.27 0.01 SC U 4 4 B - 3 3 17 4. 2 B i t R e c o r d Bi t S i z e M a k e Ty p e SN Je t s TF A De p t h In De p t h Ou t Fo o t a g e Dr i l l e d Bi t Ho u r s Av g . RO P (f t / h r ) Av g . WO B (kl b s ) Av g . RP M Avg. PP (psi) Grade 4 5 - 5 / 8 ” H u g h e s P D C 5x 1 2 0. 5 5 2 2 94 0 7 ’ 1 1 5 2 5 ’ 2 1 1 8 5 5 . 5 8 7 0 2 1 1 2 1 0 2 1-3-CT-G-X-I-ER-TD SC U 4 4 B - 3 3 18 4. 3 Mu d R e c o r d Co n t r a c t o r : B a r o i d Mu d T y p e : E Z - M u d 6 % K C l Da t e De p t h (f t ) MW (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) So l s (% ) O/ W Ra t i o Sd (% ) MB T (p p b eq . ) pH Al k (P m ) Cl (mg/L) Ca (mg/L) 5/ 0 1 / 2 0 1 4 1 0 2 8 5 9 . 5 0 4 8 1 1 1 6 5 / 8 / 1 0 4 . 6 5 . 0 0 . 0 / 9 2 . 7 0 . 1 0 1 . 0 9 . 9 0 . 2 0 2 9 0 0 0 1 0 0 5/ 0 2 / 2 0 1 4 9 3 9 0 9 . 5 0 5 2 1 2 1 8 6 / 9 / 1 2 3 . 8 4 . 8 0 . 0 / 9 2 . 7 0 . 1 0 1 . 0 9 . 8 0 . 3 0 3 0 5 0 0 1 6 0 5/ 0 3 / 2 0 1 4 9 4 0 3 9 . 5 0 4 6 1 0 1 7 5 / 7 / 1 0 4 . 5 4 . 9 0 . 0 / 9 2 . 6 0 . 2 0 1 . 0 9 . 9 0 . 2 5 3 1 0 0 0 1 2 0 5/ 0 4 / 2 0 1 4 9 4 0 7 9 . 5 2 4 6 9 1 8 5 / 8 / 1 0 4 . 6 4 . 8 0 . 0 / 9 2 . 6 0 . 1 0 1 . 0 9 . 7 0 . 2 2 3 2 0 0 0 9 0 5/ 0 5 / 2 0 1 4 9 4 1 7 9 . 5 0 4 7 1 1 1 8 6 / 9 / 1 2 4 . 3 4 . 8 0 . 0 / 9 2 . 7 0 . 2 0 1 . 0 8 . 7 0 . 1 0 3 1 5 0 0 1 2 0 5/ 0 6 / 2 0 1 4 9 6 9 2 9 . 5 5 4 8 1 3 1 7 5 / 7 / 1 0 4 . 0 4 . 9 0 . 0 / 9 2 . 4 0 . 1 0 1 . 0 1 0 . 4 0 . 6 0 3 3 0 0 0 8 0 5/ 0 7 / 2 0 1 4 1 0 2 6 8 9 . 7 5 4 6 1 4 1 6 5 / 6 / 7 3 . 3 6 . 0 0 . 0 / 9 1 . 4 0 . 0 5 1 . 2 1 0 . 3 0 . 6 0 3 3 0 0 0 8 0 5/ 0 8 / 2 0 1 4 1 0 8 1 2 1 0 . 2 0 4 8 1 7 2 1 4 / 5 / 6 3 . 0 7 . 9 0 . 0 / 8 9 . 6 0 . 1 0 2 . 5 1 0 . 5 0 . 6 0 3 2 0 0 0 8 0 5/ 0 9 / 2 0 1 4 1 1 4 8 0 1 0 . 2 0 5 0 1 9 1 9 4 / 5 / 6 2 . 8 8 . 2 0 . 0 / 8 9 . 2 0 . 0 5 2 . 5 1 0 . 3 0 . 6 0 3 3 0 0 0 7 0 5/ 1 0 / 2 0 1 4 1 1 5 2 5 1 0 . 5 0 5 4 1 8 2 0 4 / 5 / 6 2 . 6 9 . 5 0 . 0 / 8 8 . 0 0 . 1 0 2 . 5 9 . 4 0 . 2 0 3 3 0 0 0 7 0 5/ 1 1 / 2 0 1 4 1 1 5 2 5 1 0 . 5 0 4 5 1 4 1 6 4 / 5 / 6 3 . 0 9 . 5 0 . 0 / 8 8 . 0 0 . 1 0 2 . 5 9 . 0 0 . 1 0 3 3 0 0 0 6 0 5/ 1 2 / 2 0 1 4 1 1 5 2 5 1 0 . 5 5 4 5 1 3 1 6 4 / 5 / 6 2 . 8 9 . 8 0 . 0 / 8 7 . 8 0 . 1 0 2 . 5 9 . 4 0 . 2 0 3 1 0 0 0 6 0 5/ 1 3 / 2 0 1 4 1 1 5 2 5 1 0 . 5 0 4 2 1 2 1 7 4 / 5 / 6 3 . 2 9 . 5 0 . 0 / 8 8 . 0 0 . 1 0 2 . 5 9 . 2 0 . 3 0 3 0 0 0 0 6 0 5/ 1 4 / 2 0 1 4 1 1 5 2 5 1 0 . 7 0 4 8 1 5 2 0 4 / 6 / 8 3 . 0 1 0 . 4 0 . 0 / 8 7 . 4 0 . 1 0 2 . 5 9 . 4 0 . 2 5 2 9 0 0 0 6 0 5/ 1 5 / 2 0 1 4 1 1 5 2 5 1 0 . 7 0 4 9 1 6 2 0 5 / 6 / 8 3 . 0 1 0 . 2 0 . 0 / 8 7 . 4 0 . 1 0 2 . 5 9 . 9 0 . 2 5 3 2 0 0 0 6 0 5/ 1 6 / 2 0 1 4 1 1 5 2 5 1 0 . 7 0 5 0 1 5 2 1 5 / 6 / 8 3 . 0 1 0 . 2 0 . 0 / 8 7 . 4 0 . 1 0 2 . 5 9 . 4 0 . 2 3 1 0 0 0 6 0 5/ 1 7 / 2 0 1 4 1 1 5 2 5 1 0 . 7 0 4 7 1 4 2 2 4 / 6 / 8 3 . 2 1 0 . 4 0 . 0 / 8 7 . 3 0 . 1 0 2 . 5 9 . 3 0 . 3 3 0 0 0 0 4 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 P V = 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 = F i l t r a t e L o ss F C = F i l t e r C a k e S o l s = S o l i d s O/ W = O i l t o W a t e r r a t i o S d = S a n d c o n t e n t C l = C h l o r i d e s C a = H a r d n e s s SCU 44-05 19 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:10430'MD 10586'MD Country:10199'TVD 10291'TVD Averages Before During After Maximum ROP (fph)68.6 45.0 53.5 78.4 WOB 15.2 5.3 8.1 31.0 RPM 80.3 59.3 63.6 82.0 Mud Weight 10.25 10.25 10.25 10.25 Chloride 33,000 33,000 33,000 33,000 Total Gas 20 22 21 47 C1 (ppm)4,703 2,265 2,198 9,606 C2 (ppm)280 242 150 896 C3 (ppm)96 231 192 673 C4 (ppm)8 163 154 507 C5 (ppm)- 78 67 223 Lithology Cuttings Analysis Odor very slight Fluorescence Cut Fluorescence Residual Cut Stain Amount tr-40%Type burst Amount Amount trace Distribution patchy Intensity light Color Color yel brn Intensity modertate Color yel-whi Residual Fluorescence Visible Cut Color yel whi Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: bright Larry Resch/ James Foradas TRACE YELLOWISH BROWN OIL STAIN; TRACE FREE OIL IN PROCESSED SAMPLES; NOTE FLUID REMAINING IN PROCESSED SAMPLES FLUORESCES YELLOWISH WHITE; VERY SLIGHT HYDROCARBON ODOR; IMMEDIATE BURST LIGHT MILKY TO YELLOW SOLVENT REACTION; CONCENTRATED MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. none to trace1.7 milky Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/8/2014 1052 hrs Tuffaceous Sandstone, Conglomeratic Sand, Sand (10450'-10540') = interval varies from 10 to 40% loose/ disaggregate sand; poorly consolidated sandstone is grayish white to white, very light gray; upper very fine to lower fine grain; subrounded to subangular; subdiscoidal to subprismoidal; well sorted; noncalcareous; very soft, brittle; quartz sand dominant with abundant volcanic glass clasts, shards, mafic minerals poorly consolidated in a pulverulent weathered tuff/ash matrix; sublithic arenite to 'ash stone' in part note lower coarse well rounded intact pebbles and pebble fragments with high impact fracture. none Pixler Plot 1 10 100 1000 10000 1234 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:10592'MD 10663'MD Country:10295'TVD 10336'TVD Averages Before During After Maximum ROP (fph)32.6 49.3 47.9 75.0 WOB 8.1 5.7 6.7 12.0 RPM 60.1 78.3 76.4 81.0 Mud Weight 10.25 10.25 10.25 10.25 Chloride 33,000 33,000 33,000 33,000 Total Gas 16 30 34 454,802 C1 (ppm)1,487 2,979 3,366 415 C2 (ppm)138 216 243 478 C3 (ppm)144 288 350 316 C4 (ppm)99 221 259 137 C5 (ppm)60 84 105 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 40-90%Type instant Amount Amount trace Distribution even Intensity bright Color Color yel brn Intensity bright Color mky wh Residual Fluorescence Visible Cut Color yellow Intesity Color none Color Oil Show Rating Free Oil in Mud Comments Report by: none Tuffaceous Sandstone, Sand (10540'-10730') = 30 to 90% loose/ disaggregated sand; tuffaceous sandstone is white to grayish white, very light gray in part with occasional slight pale yellowish brown hues; upper very fine to lower fine grain, upper fine grain and beyond in places; subangular, occasionally angular, trace subrounded; subprismoidal to subdiscoidal; moderate to locally well sorted; noncalcareous; poorly consolidated with quartz and minor secondary dark gray to grayish black lithics, volcanic glass clasts, note local conglomeratic sand, pebbles occasional pebble fragments; note carbonaceous shale/ shaley coal at 10650'. Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/9/2014 1305 hrs bright Larry Resch/ James Foradas TRACE MEDIUM BROWN TO YELLOWISH BROWN STAIN WITH SLIGHT REDDISH HUE AT TOP OF INTERVAL, DIMINISHING WITH DEPTH; NO VISIBLE OIL BLEBS; NO ODOR; 40 TO 100% BRIGHT YELLOW SAMPLE FLUORESCENCE; SOLVENT PRODUCES INSTANT MILKY WHITE FLUORESCENT BURST WITH IMMEDIATE MILKY STREAMERS THAT DISSIPATE QUICKLY; MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. none2.4 white Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11239'MD 11451'MD Country:10701'TVD 10849'TVD Averages Before During After Maximum ROP (fph)52.3 47.7 43.7 58.7 WOB 6.2 8.6 7.3 18.0 RPM 81.0 78.8 81.4 85.0 Mud Weight 10.25 10.25 10.25 10.25 Chloride 33,000 33,000 33,000 33,000 Total Gas 13 13 7 126 C1 (ppm)1,246 1,577 1,361 21,430 C2 (ppm)63 33 28 102 C3 (ppm)51 31 7 89 C4 (ppm)58 46 7 133 C5 (ppm)48 53 - 151 Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Visible Cut Color Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: James Foradas, Larry Resch (11250'-11340') WEAK YELLOW ORANGE FLUORESCENCE 5-60%; FEINT ODOR; TRACE STAIN; SLOW MILK CUT; DULL YELLOW TO GOLD CUT; SOME STRONG RESIDUAL MILK CUT AND BRIGHT YELLOW RESIDUAL FLUORESCENCE; COMMON RING CUT TO 11310';( (11350'-11400') WEAK SLOW MILKY CUT WITH WEAK YELLOW GOLD CUT FLUORESCENCE ABOVE 11380'; NO RESIDUAL CUT. Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/9/2014 2345 hrs Tuffaceous Sandstone, Sand (11250'-11340') = light gray with white and pale brown hues; upper very fine to upper medium grained with coarser grains; poor to well sorted; subangular to subrounded; low to high sphericity; common signs of mechanical abrasion; ash matrix supported to grain supported where harder; generally soft to easily friable and intergrading to finer tuffaceous rocks in places. show zone ends in thin coal and carbonaceous shale beds between 11330'-11340'. Tuffaceous Sandstone, Conglomeratic Sand (11350'-11400') = light gray with white and pale brown hues; lower fine to very coarse; very poor to fair sorted with angular to subrounded clasts; low to moderate sphericity; common abrasion features; soft; ash matrix supported; coarsening down; interbedded with thin carbonaceous shale; Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:10706'MD 10846'MD Country:10374'TVD 10465'TVD Averages Before During After Maximum ROP (fph)48.1 37.6 36.7 92.9 WOB 7.6 9.6 0.0 41.5 RPM 77.8 70.3 43.0 93.0 Mud Weight 10.25 10.25 10.20 10.25 Chloride 33,000 33,000 33,000 33,000 Total Gas 30 25 24 53 C1 (ppm)3,393 2,613 3,788 6,026 C2 (ppm)221 148 135 381 C3 (ppm)276 200 92 503 C4 (ppm)222 163 47 388 C5 (ppm)87 82 32 170 Lithology Cuttings Analysis Odor none-slight Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-100%Type instant Amount weak-strong Amount none-slight Distribution spotty-even Intensity mod-strng Color pl-brt yellow Color Intensity none-strong Color lt. - brt.Residual Fluorescence Visible Cut none Color v. pale Yel yellow Intesity weak-strong Color brt. Yel Color pl-brt yellow Oil Show Rating Free Oil in Mud Comments Report by: Tuffaceous Sandstone, Sand (10730'-10810') = light gray with pale brown and gray white hues; upper very fine grained to upper fine grained; well to very well sorted; subrounded to round; moderate to very high sphericity; common polish; soft to unconsolidated; ash matrix supported with some harder grain supported cuttings; interbedded with tuffaceous claystone, thin carbonaceous shale and ash. Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/8/2014-5/9/2014 James Foradas, Larry Resch 40 to 90% DULL TO BRIGHT YELLOW FLUORESCENCE; INSTANT DULL TO STRONG MILK CUT AND YELLOW CUT, STRONGER RESIDUAL CUT; SHOW QUALITY DECREASES WITH DEPTH. None to 2mm scattered0.9 to 2.7 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #5 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:10882'MD 10988'MD Country:10467'TVD 10534'TVD Averages Before During After Maximum ROP (fph)40.1 39.4 51.9 81.9 WOB 0.0 3.7 4.7 7.8 RPM 53.6 80.0 89.4 92.4 Mud Weight 10.20 10.20 10.20 10.20 Chloride 33,000 33,000 33,000 33,000 Total Gas 28 38 22 66 C1 (ppm)5,017 4,297 1,798 8,439 C2 (ppm)63 268 180 503 C3 (ppm)47 354 259 674 C4 (ppm)26 222 172 429 C5 (ppm)30 109 73 213 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 10-85%Type slow-inst.Amount none Amount none Distribution spotty-patchy Intensity mod-strng Color Color Intensity weak-mod Color lt. - brt.Residual Fluorescence Visible Cut none Color v. pale Yel yellow Intesity Mod-strong Color Yel-orange Color pl-brt yellow Oil Show Rating Free Oil in Mud Comments Report by:James foradas, Larry Resch SAMPLE FLUORESCENCE 20 TO 60%, INSTANT TO SLOW PALE TO BRIGHT MILK CUT; SOME YELLOW TO BROWN CUT/RES. CUT, RING, FLUORESCENCE. SHOW IMPROVES WITH DEPTH. None to 1mm scattered1.3 to 2.3 Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/8/2014 Tuffaceous Sandstone, Sand (10810'-10900') = light gray with pale brown and gray white hues; upper very fine grained to upper coarse with some coarser; fair to well sorted; angular to well rounded; low to high sphericity; common mechanical abrasion features; unconsolidated to soft; grain supported with ash matrix; interbedded with thin coal, carbonaceous shale and tuffaceous claystone. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #6 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11002'MD 11031'MD Country:10544'TVD 10563'TVD Averages Before During After Maximum ROP (fph)51.5 48.2 49.3 70.4 WOB 4.8 6.1 4.9 8.6 RPM 89.5 89.1 89.3 91.9 Mud Weight 10.20 10.20 10.20 10.20 Chloride 33,000 33,000 33,000 33,000 Total Gas 20 41 29 63 C1 (ppm)1,676 3,141 3,014 6,709 C2 (ppm)170 367 226 682 C3 (ppm)245 511 259 645 C4 (ppm)162 346 180 452 C5 (ppm)69 158 107 262 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 90-100%Type Instant Amount Amount none Distribution Even Intensity Strong Color Color Intensity Strong Color Very Brt.Residual Fluorescence Visible Cut n/a Color Brt. Yel-Wht Yellow Intesity Color White Color Oil Show Rating Free Oil in Mud Comments Report by: none Conglomeratic Sand (10900'-11020') = overall sample color is white to grayish white to very light gray, medium to lower coarse grain; subangular to subrounded, often angular, trace well rounded; subprismoidal to subdiscoidal, prismoidal common; moderate sorting; note minor poorly consolidated upper very fine to fine grain silt/ sand grains well disseminated and entrained in very pulverulent well weathered tuff/ ash matrix; note white to grayish white very soft ashy nodules; predominantly milky to grayish white and translucent matte quartz with abundant transparent volcanic glass clasts and very fine glass shards; very minor secondary grayish black to black lithics, greenstone, orange mafic minerals; note clasts containing biotite and loose biotite flakes. Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/9/2014 1024 hrs Strong Larry Resch/ James Foradas NO STAIN OR HYDROCARBON ODOR; INTERVAL VARIES 40 TO 100% YELLOW WHITE TO BRIGHT YELLOW FLUORESCENCE; NOTE GOLD TO ORANGE TO DULL ORANGE BARACARB MINERAL FLUORESCENCE; IMMEDIATE BRIGHTENING WITH FLUORESCENT WHITE TO MILKY BURST SOLVENT REACTION AND INSTANT WISPY MILKY STREAM CUT WHICH DISSIPATES RAPIDLY; NOTE OCCASIONAL SLOWER MILKY TO LIGHT MILKY STREAMING CUT; BRIGHT WHITE TO MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. None 2.4 Brt. Yel-Wht Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #7 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11041'MD 11100'MD Country:10569'TVD 10604'TVD Averages Before During After Maximum ROP (fph)49.3 47.4 49.1 55.0 WOB 4.9 5.1 5.5 8.5 RPM 89.3 89.1 89.5 94.1 Mud Weight 10.20 10.20 10.20 10.20 Chloride 33,000 33,000 33,000 33,000 Total Gas 29 59 79 80 C1 (ppm)3,014 7,838 11,461 11,290 C2 (ppm)226 342 464 450 C3 (ppm)259 416 570 582 C4 (ppm)180 245 330 329 C5 (ppm)107 122 138 219 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 30-90%Type Instant Amount Amount none Distribution Spotty-Even Intensity Strong Color Color Intensity Mod - strong Color Very Brt.Residual Fluorescence Visible Cut none Color Brt. Yel-Org Yellow Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: bright Larry Resch/ James Foradas NO STAIN OR ODOR; 30 TO 90% YELLOW (UPPER) TO YELLOW ORANGE (LOWER) FLUORESCENCE; SOLVENT PRODUCES AN IMMEDIATE BRIGHTENING WITH INSTANT WHITE TO MILKY WHITE BURST WITH OCCASIONAL RAPIDLY DISPERSING WISPY STREAMING CUT; BRIGHT WELL DEFINED MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. none2.5 milky Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/9/2014 1351 hrs Tuffaceous Sandstone, Conglomeratic Sand, Sand (11040'-11190') = interval is dominated by a series of upward fining sequences with abundant upper medium to lower coarse subangular conglomeratic sand and pebble fragments overlain by upper very fine to fine loose/disaggregated sand, tuffaceous/ ashy/ argillaceous sandstone with occasional ash nodules, tuffaceous claystone/ siltstone; quartz dominant with minor black to grayish black lithic and mafic minerals. none Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #8 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11100'MD 11182'MD Country:10604'TVD 10662'TVD Averages Before During After Maximum ROP (fph)42.2 43.9 42.5 55.8 WOB 5.4 6.5 6.6 14.8 RPM 89.0 89.3 83.0 93.0 Mud Weight 10.20 10.20 10.20 10.20 Chloride 33,000 33,000 33,000 33,000 Total Gas 62 46 17 85 C1 (ppm)8,283 4,989 1,280 13,639 C2 (ppm)310 304 92 533 C3 (ppm)408 423 148 647 C4 (ppm)221 283 116 387 C5 (ppm)137 127 72 219 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 30-90%Type Instant Amount Amount none Distribution Spotty-Even Intensity Strong Color Color Intensity Weak-strong Color Very Brt.Residual Fluorescence Visible Cut none Color Yel-Org Yellow Intesity Color White Color Oil Show Rating Free Oil in Mud Comments Report by: Strong Larry Resch/ James Foradas NO STAIN OR ODOR; 30 TO 90% YELLOW (UPPER) TO YELLOW ORANGE (LOWER) FLUORESCENCE; SOLVENT PRODUCES AN IMMEDIATE BRIGHTENING WITH INSTANT WHITE TO MILKY WHITE BURST WITH OCCASIONAL RAPIDLY DISPERSING WISPY STREAMING CUT; BRIGHT WELL DEFINED MILKY WHITE FLUORESCENT RING; NO VISIBLE RESIDUE. None to 1mm scattered0.5 to 2.4 Very Brt.Milk Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/9/2014 1331 hrs Tuffaceous Sandstone, Conglomeratic Sand, Sand (11040'-11190') = interval is dominated by a series of upward fining sequences with abundant upper medium to lower coarse subangular conglomeratic sand and pebble fragments overlain by upper very fine to fine loose/disaggregated sand, tuffaceous/ ashy/ argillaceous sandstone with occasional ash nodules, tuffaceous claystone/ siltstone; quartz dominant with minor black to grayish black lithic and mafic minerals. none Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #9 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:11239'MD 11336'MD Country:10701'TVD 10768'TVD Averages Before During After Maximum ROP (fph)44.2 45.4 47.1 58.7 WOB 6.2 10.2 16.0 18.8 RPM 82.9 82.3 80.8 85.9 Mud Weight 10.20 10.20 10.20 10.20 Chloride 33,000 33,000 33,000 33,000 Total Gas 12 17 12 126 C1 (ppm)1,073 1,924 1,761 21,430 C2 (ppm)60 42 21 102 C3 (ppm)64 49 32 89 C4 (ppm)59 69 46 133 C5 (ppm)47 52 21 100 Lithology Cuttings Analysis Odor none Fluorescence Cut Fluorescence Residual Cut Stain Amount 5-60%Type very slow Amount Amount 0- trace Distribution Patchy Intensity v. wk-mod Color Color Yel - brn Intensity v. weak-mod Color none-light Residual Fluorescence Visible Cut none Color Yel-orange Yellow Intesity Color Color Oil Show Rating Free Oil in Mud Comments Report by: v. wk-mod James Foradas, Larry Resch WEAK YELLOW ORANGE FLUORESCENCE 5-60%; FEINT ODOR; TRACE STAIN; SLOW MILK CUT; DULL YELLOW TO GOLD CUT; SOME STRONG RESIDUAL MILK CUT AND BRIGHT YELLOW RESIDUAL FLUORESCENCE; COMMON RING CUT TO 11310'. None to 1mm scattered06 to 1.6 v.pale to yel-org Kenai Borough Alaska USA Hilcorp Alaska, LLC 50-133-10170-01-00SCU 44B-33 Swanson River Field Saxon 169 5/9/2014 1759 hrs Tuffaceous Sandstone, Sand (11250'-11340') = light gray with white and pale brown hues; upper very fine to upper medium grained with coarser grains; poor to well sorted; subangular to subrounded; low to high sphericity; common signs of mechanical abrasion; ash matrix supported to grain supported where harder; generally soft to easily friable and intergrading to finer tuffaceous rocks in places; show zone ends in thin coal and carbonaceous shale beds between 11330'-11340' Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 SCU 44-05 20 6 DAILY REPORTS Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jim Greco DATE: May 02, 2014 DEPTH 9390' PRESENT OPERATION: Orienting Whipstock TIME: 23:59:42 YESTERDAY 9390' 24 HOUR FOOTAGE 0' CASING INFORMATION 6.625" @ 9390' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9390'/9390' MW 9.5 VIS 52 PV 12 YP 18 Gels 8/9/12 FL 3.8 FC 1/2 SOL 4.8 NAF/W 0/92.7 SD 0.1 MBT 1.0 pH 9.8 ALK 0.3 Cl- 30500 Ca+ 160 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 2 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY N/A. In cased hole DAILY ACTIVITY SUMMARY Completed rigup of Canrig DML logging unit and gas sampling system. The rig continued POOH; L/D scraper assembly; R/U Eline to orient whipstock; currently orienting whipstock, CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas __DAILY COST: $2048.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jim Greco DATE: May 03, 2014 DEPTH 9402' PRESENT OPERATION: Drilling rathole for FIT TIME: 23:59:21 YESTERDAY 9381' 24 HOUR FOOTAGE 21' CASING INFORMATION 6.625' @ 9390' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED Mill Bit DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 9.8 @ 9392' 0.3 @ 9384' 3.4 3.55738 FT/HR SURFACE TORQUE 8502 @ 9387' 2328 @ 9402' 4836.7 2328.09009 FT-LBS WEIGHT ON BIT 21 @ 9402' 0 @ 9381' 9.3 21.19000 KLBS ROTARY RPM 94 @ 9402' 87 @ 9393' 95.4 94.00000 RPM PUMP PRESSURE 1482 @ 9402' 1107 @ 9393' 1311.1 1482.89001 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9402'/9402' MW 9.5 VIS 46 PV 10 YP 17 Gels 5/7/10 FL 4.5 FC 1/2 SOL 4.9 NAF/W 0/92.6 SD 0.2 MBT 1.0 pH 9.9 ALK .25 Cl- 31000 Ca+ 120 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 9395' 0 @ 9385' 2.7 TRIP GAS CUTTING GAS 0 @ 9402' 0 @ 9402' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 162 @ 9381' 162 @ 9381' 7.7 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 9402' 0 @ 9402' 0.0 CONNECTION GAS: AVG PROPANE (C-3) 0 @ 9402' 0 @ 9402' 0.0 CONNECTION GAS: CURRENT BUTANE (C-4) 0 @ 9402' 0 @ 9402' 0.0 CURRENT AVG BACKGROUND PENTANE (C-5) 0 @ 9402' 0 @ 9402' 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY sand PRESENT LITHOLOGY sand mixed with metal from milling of window DAILY ACTIVITY SUMMARY Continue RIH with E-line to orient whipstock. RIH with DP and tagged CIBP at 9,397'. RIH with E-line and oriented whipstock, set at 9,380'; displaced well from produced water to 9.5 ppg 6% KCL/PHPA mud; Began milling window, Top at 9,380', bottom at 9,392'; pumped hi-vis sweep at 9,388' observing 20% increase in cuttings; pumped hi-vis sweep at 9,398', observing 10% increase in cuttings, mostly sand w/ some fine metal; collected 128 lbs. of metal cuttings at shakers; continued drilling ahead to 9,403'; currently pumping hi-vis sweep at 9402’. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $3127.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jim Greco DATE: May 04, 2014 DEPTH 9407' PRESENT OPERATION: POOH TIME: 23:59:41 YESTERDAY 9403' 24 HOUR FOOTAGE 4' CASING INFORMATION 6.625 @ 9390' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED Mill Bit DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9407'/9407' MW 9.52 VIS 46 PV 9 YP 18 Gels 5/8/10 FL 4.6 FC 1/2 SOL 4.8 NAF/W 0/92.6 SD 0.1 MBT 1.0 pH 9.7 ALK .22 Cl- 32000 Ca+ 90 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 4 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY sand PRESENT LITHOLOGY sand mixed with cuttings from milling DAILY ACTIVITY SUMMARY Circulated out hi-vis sweep, observing 10% increase in cuttings, mostly fine sand with no visible metal; conducted FIT to 12.0 ppg EMW; pumped dry job and POOH from 9,360' to surface. P/U new mill bit and 33 singles; RIH washing and reaming from 9,380' to 9,407'; pumped hi-vis sweep at 9,377', observing no increase in cuttings; pumped dry job and POOH; currently POOH at 8,502’. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jim Greco DATE: May 05, 2014 DEPTH 9417' PRESENT OPERATION: Drilling TIME: 23:59:05 YESTERDAY 9407' 24 HOUR FOOTAGE 10' CASING INFORMATION 6.625 @ 9390' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5.625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 38.9 @ 9417' 15.0 @ 9413' 24.7 38.90617 FT/HR SURFACE TORQUE 0 @ 9417' 0 @ 9417' 0.0 0.00000 FT-LBS WEIGHT ON BIT 20 @ 9407' 10 @ 9414' 16.8 12.55000 KLBS ROTARY RPM 0 @ 9417' 0 @ 9417' 0.0 0.00000 RPM PUMP PRESSURE 1918 @ 9417' 1834 @ 9412' 1872.2 1918.28003 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9417'/9417' MW 9.5 VIS 47 PV 11 YP 18 Gels 6/9/12 FL 4.3 FC 1/2 SOL 4.8 NAF/W 0.0/92.7 SD 0.1 MBT 1.0 pH 8.7 ALK 0.1 Cl- 31500 Ca+ 120 MWD SUMMARY INTERVAL 9407' TO TOOLS Bit, directional and Gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ 9415' 0 @ 9408' 1.8 TRIP GAS 2 CUTTING GAS 0 @ 9417' 0 @ 9417' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 645 @ 9415' 70 @ 9408' 365.9 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 9417' 0 @ 9417' 0.0 CONNECTION GAS: AVG PROPANE (C-3) 0 @ 9417' 0 @ 9417' 0.0 CONNECTION GAS: CURRENT BUTANE (C-4) 0 @ 9417' 0 @ 9417' 0.0 CURRENT AVG BACKGROUND PENTANE (C-5) 0 @ 9417' 0 @ 9417' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek formation PRESENT LITHOLOGY Tuffaceous siltstone (40%), tuffaceous claystone (30%), tuffaceous shale (10%), tuffaceous sandstone (10%), sand (10%) DAILY ACTIVITY SUMMARY Continued POOH from 8502’ to surface; L/D milling assembly; P/U directional BHA (BHA#4); RIH to 9,404'; R/U wireline with side entry sub and test; Drill ahead from 9,407'; currently drilling at 9417’. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jim Greco DATE: May 06, 2014 DEPTH 9694' PRESENT OPERATION: Drilling TIME: 23:59:27 YESTERDAY 9417' 24 HOUR FOOTAGE 277' CASING INFORMATION 6.625" @ 9390' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9516.32' 13.02 280.86 9514.57' 9547.31' 13.15 269.62 9544.76' 9578.67' 14.20 254.19 9575.24' 9609.37' 16.36 250.69 9504.86' 9639.41' 16.46 248.64 9633.67' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5.625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 65.8 @ 9431' 1.3 @ 9427' 35.0 33.38710 FT/HR SURFACE TORQUE 6620 @ 9593' 3515 @ 9644' 1997.0 0.00000 FT-LBS WEIGHT ON BIT 29 @ 9669' 0 @ 9560' 12.3 18.99000 KLBS ROTARY RPM 50 @ 9624' 1 @ 9430' 18.1 0.00000 RPM PUMP PRESSURE 2052 @ 9644' 1742 @ 9473' 1906.1 1913.55005 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 9,692'/9,671' MW 9.55 VIS 48 PV 13 YP 17 Gels 5/7/10 FL 4.0 FC 1/2 SOL 4.9 NAF/W 0.0/92.4 SD 0.1 MBT 1.0 pH 10.4 ALK 0.6 Cl- 33000 Ca+ 80 MWD SUMMARY INTERVAL 9407' TO 9694' TOOLS Bit, directional and Gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ 9478' 0 @ 9489' 5.2 TRIP GAS N/A CUTTING GAS 0 @ 9694' 0 @ 9694' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 6705 @ 9478' 130 @ 9489' 1010.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 74 @ 9604' 0 @ 9660' 3.2 CONNECTION GAS: AVG 0 PROPANE (C-3) 23 @ 9561' 0 @ 9546' 0.6 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 9694' 0 @ 9694' 0.0 CURRENT AVG BACKGROUND 5/3 PENTANE (C-5) 0 @ 9694' 0 @ 9694' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Tyonek formation PRESENT LITHOLOGY Tuffaceous sandstone(90%), tuffaceous siltstone (10%) DAILY ACTIVITY SUMMARY Continued drilling ahead from 9417', rigging down wireline in the process; currently drilling ahead at 9694’ CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grub, Jay Sweetsir DATE: May 07, 2014 DEPTH 10285' PRESENT OPERATION: Drilling TIME: 23:59:06 YESTERDAY 9694' 24 HOUR FOOTAGE 591' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10020.71' 49.58 256.95 9950.73' 10050.91' 51.66 257.03 9969.89' 10085.50' 53.03 256.70 9991.03' 10112.69' 52.88 256.22 10007.41' 10177.40' 52.74 256.5 10046.52' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5.625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 159.6 @ 9785' 1.4 @ 10059' 52.4 60.09746 FT/HR SURFACE TORQUE 8519 @ 10159' 3930 @ 10156' 3221.5 6213.41992 FT-LBS WEIGHT ON BIT 34 @ 9773' 0 @ 9897' 14.4 16.81000 KLBS ROTARY RPM 73 @ 10156' 1 @ 9814' 35.5 65.88000 RPM PUMP PRESSURE 2165 @ 10285' 1838 @ 9701' 2013.0 2165.60010 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 10268'/10073' MW 9.75 VIS 46 PV 14 YP 16 Gels 5/6/7 FL 3.3 FC 1/2 SOL 6.0 NAF/W 0.0/91.4 SD 0.05 MBT 1.2 pH 10.3 ALK 0.6 Cl- 33000 Ca+ 80 MWD SUMMARY INTERVAL 9407' TO 10,285' TOOLS Bit, directional and Gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 111 @ 10124' 1 @ 10265' 26.2 TRIP GAS N/A CUTTING GAS 0 @ 10285' 0 @ 10285' 0.0 WIPER GAS 0u CHROMATOGRAPHY (ppm) SURVEY 93u METHANE (C-1) 23013 @ 10124' 336 @ 9706' 5396.7 CONNECTION GAS HIGH 485u ETHANE (C-2) 595 @ 10141' 0 @ 9892' 33.8 CONNECTION GAS: AVG 178.8u PROPANE (C-3) 219 @ 10141' 1 @ 10162' 6.1 CONNECTION GAS: CURRENT 244u BUTANE (C-4) 0 @ 10285' 0 @ 10285' 0.0 CURRENT AVG BACKGROUND 26u/23u PENTANE (C-5) 0 @ 10285' 0 @ 10285' 0.0 HYDROCARBON SHOWS Oil Show at 10080-10110' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11080-11110 Tuffaceous sandstone; some oil seen flowing over shakers; well flowing at 6bbl/hr 51- 82units <5% dull yellow sample fluorescence; no cut. Oil in mud showing yellow fluor, yellow cut fluor. and instant milk cut. LITHOLOGY Tyonek formation PRESENT LITHOLOGY Tuffaceous sandstone (70%), tuffaceous claystone (30%); traces ash, carbonaceous shale. DAILY ACTIVITY SUMMARY Continued drilling ahead from 9694' to 9835' and observed the well to be flowing 1 bph; continued drilling ahead to 10,088'; observed well flowing at 6.2 bph with connection gas at 485 units; decision was made to increase MW to 9.7+ ppg; continued drilling ahead to 10,212' and flow checked; flow at 8 bph and connection gas at 451 units; decision made to increase MW to 10.0 ppg while drilling ahead; last connection gas was 244 units, currently drilling at 10285’. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jay Sweetsir DATE: May 08, 2014 DEPTH 10812' PRESENT OPERATION: Drilling TIME: 23:59:14 YESTERDAY 10285' 24 HOUR FOOTAGE 527' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10491.15 ' 54.37 258.68 10235.78' 10553.74' 54.56 258.65 10272.15' 10616.39' 54.26 257.79 10308.62' 10678.88' 54.15 258.31 10345.17' 10741.31' 53.77 259.13 10381.90' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5.625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 92.9 @ 10804' 4.1 @ 10288' 48.0 14.26667 FT/HR SURFACE TORQUE 8488 @ 10668' 3678 @ 10286' 5705.3 4840.97021 FT-LBS WEIGHT ON BIT 41 @ 10812' 0 @ 10540' 10.7 41.52000 KLBS ROTARY RPM 92 @ 10761' 1 @ 10481' 66.2 41.63000 RPM PUMP PRESSURE 2392 @ 10696' 1978 @ 10730' 2192.5 2168.06006 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 10812'/10423' MW 10.2 VIS 48 PV 17 YP 21 Gels 4/5/6 FL 3.0 FC 1/2 SOL 7.9 NAF/W 0.0/89.6 SD 0.1 MBT 2.5 pH 10.5 ALK 0.6 Cl- 32000 Ca+ 80 MWD SUMMARY INTERVAL 9407' TO 10812' TOOLS Bit, directional and Gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 81 @ 10339' 4 @ 10378' 24.2 TRIP GAS 8u CUTTING GAS 0 @ 10812' 0 @ 10812' 0.0 WIPER GAS 507u CHROMATOGRAPHY (ppm) SURVEY 0u METHANE (C-1) 18405 @ 10339' 620 @ 10572' 3184.6 CONNECTION GAS HIGH 260u ETHANE (C-2) 896 @ 10437' 2 @ 10379' 183.2 CONNECTION GAS: AVG 167u PROPANE (C-3) 673 @ 10504' 0 @ 10358' 191.8 CONNECTION GAS: CURRENT n/a BUTANE (C-4) 507 @ 10504' 0 @ 10379' 139.1 CURRENT AVG BACKGROUND 10u PENTANE (C-5) 223 @ 10500' 3 @ 10437' 62.7 HYDROCARBON SHOWS Three oil show zones between 10450' and 10810' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10450-10550 10580-10650 10670-10800 congolmeratic sand, tufaceous sandstone. congolmeratic sand, tufaceous sandstone. tufaceous sandstone, sand. 35-45u 25-40u 30-45u oil show oil show oil show LITHOLOGY Hemlock SRH1ST sand PRESENT LITHOLOGY Tuffaceous sandstone/sand (80%), coal (10%), ash (10%) DAILY ACTIVITY SUMMARY Drilled from10,285' to10,338', flow checked well during connections; flow at 10 bph, increased MW to 10.1ppg; drilled to10,400' and flow reduced to 8.5 bph; began weight up to 10.3ppg, but decision was made to continue drilling ahead with current 10.2 ppg MW. Pumped 20bbl Hi-Vis sweep at 10,550' seeing 50% increase in cuttings; continued drilling to10,705'; tried to slide, but string began to differentially stick; pumped another 20 bbl Hi-Vis sweep with no increase in cuttings observed; drilled ahead to 10,802’; CBU; POOH to10,339' to wipe hole; RIH to10,802’; drilled ahead slowly; currently at 10812’. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jay Sweetsir DATE: May 09, 2014 DEPTH 11486' PRESENT OPERATION: Drilling, TIME: 23:59:55 YESTERDAY 10812' 24 HOUR FOOTAGE 674 CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11121.34' 48.50 259.74 10621.90' 11184.40' 47.65 259.09 10664.00' 11247.57' 46.76 259.14 10706.92' 11310.44' 46.36 258.85 10750.15' 11372.96' 45.45 258.33 10793.65' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5.625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 85.1 @ 10990' 0.4 @ 10830' 43.9 50.99592 FT/HR SURFACE TORQUE 9894 @ 11395' 574 @ 10828' 7014.7 8553.26953 FT-LBS WEIGHT ON BIT 41 @ 10812' 0 @ 10818' 6.2 18.92000 KLBS ROTARY RPM 94 @ 10873' 2 @ 10888' 80.5 79.26000 RPM PUMP PRESSURE 2602 @ 11385' 2137 @ 10828' 2381.7 2426.27002 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,480'/10,865' MW 10.2 VIS 50 PV 19 YP 19 Gels 4/5/6 FL 2.8 FC 1/2 SOL 8.2 NAF/W 0.0/89.2 SD 0.1 MBT 2.5 pH 10.4 ALK 0.6 Cl- 33000 Ca+ 70 MWD SUMMARY INTERVAL 9407' TO 11,486' TOOLS Bit, directional and Gamma GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 127 @ 10876' 6 @ 11464' 27.1 TRIP GAS N/A CUTTING GAS 0 @ 11486' 0 @ 11486' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 24604 @ 10876' 714 @ 11405' 3172.3 CONNECTION GAS HIGH 231u ETHANE (C-2) 957 @ 10850' 0 @ 11435' 159.8 CONNECTION GAS: AVG 143.8u PROPANE (C-3) 712 @ 11032' 0 @ 11485' 200.9 CONNECTION GAS: CURRENT 150u BUTANE (C-4) 472 @ 11032' 0 @ 11485' 138.5 CURRENT AVG BACKGROUND 7u PENTANE (C-5) 277 @ 11032' 0 @ 10846' 76.6 HYDROCARBON SHOWS Three Oil Shows INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10812'-11020' 11050'-11190' 11260'-11330' Tuffaceous sandstone, conglomeratic sanstone Tuffaceous sandstone Tuffaceous sandstone, 14-65 units 14-81 units 7-13 units Oil show continuing from yesterday Oil show Oil show LITHOLOGY Hemlock formation PRESENT LITHOLOGY Tuffaceous sandstone (10%); tuffaceous siltstone (40%), tuffaceous claystone (40%), sand (10%) DAILY ACTIVITY SUMMARY Continued drilling ahead from 10,812'; and checked flow at connection; flow continued to hold at 10bph; increased background LCM to 30ppb; checked flow at 11,387' and flow was 8bph; currently drilling ahead at 11,486’MD. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jay Sweetsir DATE: May 10, 2014 DEPTH 11525' PRESENT OPERATION: POOH TIME: 23:59:09 YESTERDAY 11486' 24 HOUR FOOTAGE 39' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11310.44' 46.36 258.85 10750.15' 11372.96' 45.45 258.33 10793.65' 11435.07' 44.17 258.87 10837.71' 11484.98' 43.44 258.69 10873.73' 11525.00' 43.44 258.69 10902.79' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5.625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' 11525' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 54.7 @ 11511.00000 32.2 @ 11502.00000 46.6 33.70000 FT/HR SURFACE TORQUE 10244 @ 11523.00000 6488 @ 11487.00000 9198.8 8760.00000 FT-LBS WEIGHT ON BIT 19 @ 11488.00000 7 @ 11520.00000 9.5 10.30000 KLBS ROTARY RPM 90 @ 11494.00000 79 @ 11486.00000 88.9 85.00000 RPM PUMP PRESSURE 2468 @ 11502.00000 2378 @ 11487.00000 2500.6 2435.00000 PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525'/10,903' MW 10.5 VIS 54 PV 18 YP 20 Gels 4/5/6 FL 2.6 FC 1/2 SOL 9.5 NAF/W 0.0/88.0 SD 0.1 MBT 2.5 pH 9.4 ALK 0.2 Cl- 33000 Ca+ 70 MWD SUMMARY INTERVAL 9407' TO 11525' TOOLS Bit, directional and Gamma; presently being pulled out of hole GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 8 @ 11491' 5 @ 11521' 5.9 TRIP GAS 663u CUTTING GAS 0 @ 11525' 0 @ 11525' 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 1508 @ 11494' 803 @ 11512' 1099.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 49 @ 11486' 1 @ 11511' 15.6 CONNECTION GAS: AVG 0 PROPANE (C-3) 0 @ 11525' 0 @ 11525' 0.0 CONNECTION GAS: CURRENT 0 BUTANE (C-4) 0 @ 11525' 0 @ 11525' 0.0 CURRENT AVG BACKGROUND 1u PENTANE (C-5) 0 @ 11525' 0 @ 11525' 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Hemlock formation (TD) PRESENT LITHOLOGY Tuffaceous sandstone (20%); tuffaceous siltstone (30%), tuffaceous claystone (30%), coal (10%), sand (10%), DAILY ACTIVITY SUMMARY Drilled to TD at 11,525'; CBU (67 units); pumped a 20bbl hi-vis sweep seeing 10% increase in cuttings; spotted a 70bbl 50ppb pill with a MW of 10.5ppg and a 80 Vis on bottom; began POOH, pulling hard from 11,525' to 10,680 with 40-50K over; continued POOH to into the window; slipped and cut drill line while monitoring well, flow 7-8bph; decision made to RIH to bottom, weigh up, and spot another pill; RIH to bottom; weighed up to 10.55ppg MW; CBU (663units); dumped 40bbl fresh water from formation; began POOH; currently POOH at 2033’. CANRIG PERSONNEL ON BOARD: L. Resch, J. Foradas, B. Calo, F. Spiers __DAILY COST: $2877.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, Jay Sweetsir DATE: May 11, 2014 DEPTH 11525' PRESENT OPERATION: Working stuck pipe TIME: 23:59:09 YESTERDAY 11525' 24 HOUR FOOTAGE 0 CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED 4 5 .625" Hughes DP405S PDC 7029510 5x12/0.5522 9407' 11525' 2118' 55.5 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525/10,903' MW 10.5 VIS 45 PV 14 YP 16 Gels 4/5/6 FL 3.0 FC 1/2 SOL 9.5 NAF/W 0.0/88.0 SD 0.1 MBT 2.5 pH 9.0 ALK 0.1 Cl- 33000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 690u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 6u PENTANE (C-5) @ @ HYDROCARBON SHOWS N/A INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TD in Lower Hemlock formation / Presently stuck in the Tyonek formation PRESENT LITHOLOGY Tuffaceous sandstone (20%); tuffaceous siltstone (30%), tuffaceous claystone (30%), coal (10%), sand (10%), DAILY ACTIVITY SUMMARY Finished TOOH, L/D BHA, Flow check while out of the hole was 6bph; M/U LWD assembly for Mad Pass and TIH to window; began seeing gas at possum belly when filling DP; decision made to CBU @ 7000'; Dumped 21 bbl H2O from formation, lowest weight was 8.9ppg and max gas was 690 units; continued RIH to window; CBU- dumped 100 bbl H2O from formation; owest MW was 8.3 ppg and max gas was 640 units; TIH to 9584' and became stuck. Attempts to free stuck pipe included pumping a 20 bbl hi-vis 40 ppb sweep, which resulted in a 25% increase in cuttings mostly tuffaceous siltstone (40%), tuffaceous sandstone (30%), and tuffaceous claystone (30%) with traces of coal (1-2%), and additives used for the sweep; we have been working stuck pipe since 5:30 PM. CANRIG PERSONNEL ON BOARD: J. Foradas, L. Resch, J. Adams, B. Calo, Fred Spiers __DAILY COST: $2925.00 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, James Sweetsir DATE: May 12, 2014 DEPTH 11525' PRESENT OPERATION: Testing BOPs TIME: 23:59:32 YESTERDAY 11525' 24 HOUR FOOTAGE 0' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525/10,903 MW 10.55 VIS 45 PV 13 YP 16 Gels 4/5/6 FL 2.8 FC 1/2 SOL 9.8 NAF/W 0.0/87.8 SD 0.1 MBT 2.5 pH 9.4 ALK 0.2 Cl- 31000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 334 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Hemlock formation PRESENT LITHOLOGY No drilling past 24hrs. DAILY ACTIVITY SUMMARY DP Freed up at 00:30, reciprocated pipe during CBU; which exhibited minor increase in cuttings composed of tuffaceous siltstone (40%), tuffaceous sandstone (30%), and coal (30%); pumped a 20 bbl Hi-Vis sweep while reciprocating, with no increase in cuttings. TOOH to 9523’; jarring down and backreaming to 9300'; performed derrick inspection; slip and cut drill line; Flow-checked well (4.8 bph flow); decided to POOH; spotted 50bbl, 12.5ppg and 80 Vis pill at window; POOH 10 stands and flow-check (4.0 bph flow); POOH to above window; pumped a second similar pill chasing it with 61 bbl and pumping remaining (20 bbl) as a slug; flow-check (2.5 bph flow); POOH 10 stands and flow-check (well static); POOH to HWDP, flow-check (4.2 bph flow). Began testing BOP's and flow check (4.7 bph flow); currently testing BOP's. CANRIG PERSONNEL ON BOARD: J. Foradas, J. Adams __DAILY COST: $2048.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, James Sweetsir DATE: May 13, 2014 DEPTH 11525' PRESENT OPERATION: RIH Circulating/Reaming TIME: 23:59:32 YESTERDAY 11525' 24 HOUR FOOTAGE 0' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525'/10,903' MW 10.50 VIS 42 PV 12 YP 17 Gels 4/5/6 FL 3.2 FC 1/2 SOL 9.5 NAF/W 0.0/88.2 SD 0.1 MBT 2.5 pH 9.2 ALK 0.3 Cl- 30,000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 184u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Hemlock formation PRESENT LITHOLOGY No drilling past 24hrs. DAILY ACTIVITY SUMMARY Finished testing BOP's, well flow avg. 4.5bph during tests; P/U BHA and TIH to 4800' and observed water at surface; TIH 9351'; circulated out 216bbls of H2O/Mud, mostly 8.4 ppg (800 mg/L Cl-) and 184units of gas; started taking back returns into the active at 10.2 ppg MW; started circulating and reaming to bottom at 9450'; currently reaming at 9497’ MD. CANRIG PERSONNEL ON BOARD: J. Foradas, J. Adams __DAILY COST: $2048.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grub, James Sweetsir DATE: May 14, 2014 DEPTH 11525' PRESENT OPERATION: BROOH TIME: 23:59:56 YESTERDAY 11525' 24 HOUR FOOTAGE 0' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525'/10,903' MW 10.7 VIS 48 PV 15 YP 20 Gels 4/6/8 FL 3.0 FC 1/2 SOL 10.4 NAF/W 0.0/87.4 SD 0.1 MBT 2.5 pH 8.9 ALK 0.25 Cl- 29000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 53u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Hemlock formation PRESENT LITHOLOGY No drilling past 24hrs. DAILY ACTIVITY SUMMARY Continued RIH, reaming to 10,300'; pumped 20bbl hi-vis sweep, observing 150% increase in cuttings (54u trip gas); RIH, reaming to bottom; pumped Hi-Vis sweep observing 30% increase in cuttings and barite and 11u gas; started logging while BROOH from bottom to window, which is currently in progress. CANRIG PERSONNEL ON BOARD: J. Foradas, J. Adams __DAILY COST: $2048.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grub, James Sweetsir DATE: May 15, 2014 DEPTH 11525' PRESENT OPERATION: RIH with Liner TIME: 23:59:45 YESTERDAY 11525' 24 HOUR FOOTAGE 0' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525'/10,903' MW 10.7 VIS 49 PV 16 YP 20 Gels 5/6/8 FL 3.0 FC 1/2 SOL 10.2 NAF/W 0.0/87.4 SD 0.10 MBT 2.5 pH 9.9 ALK 0.4 Cl- 32000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1125u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Hemlock formation PRESENT LITHOLOGY No drilling past 24hrs. DAILY ACTIVITY SUMMARY Finished Logging to window; pulled up into the CSG; serviced rig; CBU with flow at 4.7bph; RIH to bottom on elevators rotate and pump through tight spot at 9775’ ; pumped a 20 bbl Hi-Vis sweep with CBU (maximum gas 1125 unit), observed no increase in cuttings ; spotted 100bbl 100ppb LCM pill on bottom; TOOH to 8613'; spotted 63bbl Hi-vis and barite pill (12.5 ppg); dropped rabbit; L/D 73 joints of 4" DP; TOOH, well flowing at 2.8bbls/hr. R/U Weatherford to run liner; RIH with Liner. CANRIG PERSONNEL ON BOARD: J. Foradas, J. Adams __DAILY COST: $2048.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, James Sweetsir DATE: May 16, 2014 DEPTH 11525' PRESENT OPERATION: Running 4" Liner TIME: 23:59:34 YESTERDAY 11525' 24 HOUR FOOTAGE 0' CASING INFORMATION 6.625" @ 9690' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD 11,525'/10,903' MW 10.7 VIS 50 PV 15 YP 21 Gels 5/6/8 FL 3.0 FC 1/2 SOL 10.2 NAF/W 0.0/87.4 SD 0.10 MBT 2.5 pH 9.5 ALK 0.20 Cl- 31000 Ca+ 60 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 141u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND 108u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Hemlock formation PRESENT LITHOLOGY No drilling past 24hrs. DAILY ACTIVITY SUMMARY Started RIH with 4” Liner; over torqued landing collar; waited on new collar to arrive from town; resumed RIH with 4" liner, well flowing at 4 bbls/hr; currently RIH at 8203’ MD with background gas beginning to increase steadily to present background level after filling pipe at 6803’ MD. CANRIG PERSONNEL ON BOARD: J. Foradas, J. Adams __DAILY COST: $2048.50 REPORT BY: J. Foradas Hilcorp Alaska, LLC DAILY WELLSITE REPORT SCU 44B-33 REPORT FOR: Joe Grubb, James Sweetsir DATE: May 17, 2014 DEPTH 11525' PRESENT OPERATION: Cementing TIME: 13:32:09 YESTERDAY 11525' 24 HOUR FOOTAGE 0 CASING INFORMATION 6.625" @ 9690' 4" @ 11403' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS/ TFA IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MD/ TVD Not Available at report time MW VIS PV YP Gels FL FC SOL NAF/W SD MBT pH ALK Cl- Ca+ MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 1162u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ CONNECTION GAS: AVG PROPANE (C-3) @ @ CONNECTION GAS: CURRENT BUTANE (C-4) @ @ CURRENT AVG BACKGROUND N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Lower Hemlock formation PRESENT LITHOLOGY No drilling past 24hrs. DAILY ACTIVITY SUMMARY Continued RIH with 4” Liner; landing at 11,403’; CBU returned 1162 units gas; R/U Cementers and pump cement; Canrig Logging Crew released and started DML Mudlogging Unit rigdown. CANRIG PERSONNEL ON BOARD: J. Foradas, J. Adams __DAILY COST: $2048.50 REPORT BY: J. Foradas