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Home My WebLink About215-1001. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 4,470 feet See Schematic feet true vertical 4,162 feet 3,423 feet Effective Depth measured 2,810 feet 1,981 & 4,238 feet true vertical 2,518 feet 1,807 & 3,930 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Baker Swell Pkr, 1,981' MD 1,807' TVD Packers and SSSV (type, measured and true vertical depth)Model D Perm Pkr, N/A 4,238' MD 3,930' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Chad Helgeson, Operations Engineer 323-277 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 chelgeson@hilcorp.com 907-777-8405 N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 0 Size 120' 0 00 0 1460 141 measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-100 50-133-20652-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028406 Swanson River / Sterling-Upper Beluga Gas Swanson River Unit (SRU) 213-15 Plugs Junk measured Length Production Liner 4,466' Casing Structural 4,158'4,466' 120'Conductor Surface Intermediate 13-3/8" 7-5/8" 120' 2,525' 7,500psi 6,890psi 8,430psi 2,525' 2,265' Burst Collapse 4,790psi p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:52 am, Aug 29, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2023.08.28 16:37:56 - 08'00' Noel Nocas (4361) Rig Start Date End Date 7/20/23 8/1/23 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00-00 215-100 07/20/2023 - Thursday YJ Eline arrives at SRF office, signs in, obtains PTW and holds PJSM. Mobilize equipment to location. Production has well on lift gas to depress fluid away for plug and perf. Spot equipment and MU PCE and tool string. 2.75" OD GPT, Wt. bar and junk basket with 3.625" GR. Move to well head and PT 250L/3000H. Pass. 2458 SITP Open swab and RIH logging down pass to locate fluid level. Discovered gas cut fluid at 2420' and true fluid level at 2520'. (415' above proposed A-10 perfs) Tagged PBTD at 2877'. POOH. OOH. MU 2.75" GR/CCL, wt. bar and setting tool with 3.50" CIBP. (CCL to CIBP - 19'). Open swab and RIH. Ran correlation pass and tagged PBTD at 2863' (14' higher than JBGR). Confirmed to set plug at 2863'. Positioned and set CIBP at 2863'. POOH. OOH. LD setting tool and MU 10' x 3.50" cement dump bailer. Mix 3 gal.of cement, fill bailer and stab on well. Bleed tubing down to 850 psi. Open swab and RIH. Tag CIBP, PU and dump cement. Est. TOC - 2858'. POOH. OOH. LD bailer and MU 2.75" x 10' (6spf/60Deg) perf gun loaded with GeoDynamics 15 gm charges. (CCL to top shot - 16.5'). Open swab and RIH. Bleed well down to 700 psi. Run correlation pass, confirm on depth, position gun at 2818.5' (CCL depth) and fire gun in the A-10 sand (2835' - 2845'). POOH Initial - 700 psi 5min - 740 psi 10 min. - 740 psi 15 min - 740 psi LD spent gun. all shots fired. Bull plug filled with sandy slurry. Nightcap well head and turn well over to production to flow back. Open wing and flowback at 500 mcfd. Draw down to 500 psi (15 min.) No sustained flow and only slight pressure build after SI. MU GPT tool string. SITP - 550 psi. Open swab and RIH w/ log survey. Located fluid level at 1784' (1051' above top perf). Tagged PBTD at 2750' (85' above top perf). OOH. Secure well for production to apply lift gas. RDMO E-line. 07/21/2023- Friday SL crew arrives, Completes JSA and work permit. RU, PT Lubricator, failed. C/O needle valve, Passed 2500 psi pressure test RIH w/ 3" DD bailer to 2732. POOH w/ 6" solids Use 2.5" DD bailer and bail from 2734-2738'. Run Blind Box to find fluid level at 1725'KB Bled pressure from 1000 psi to 500 psi easier bailing operations with lower pressure Rig down equipment Rig Start Date End Date 7/20/23 8/1/23 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00-00 215-100 SL Arrives in field. Complete Permit w/ LO and conducts a TGSM MIRU unit. PT to 2500 psi, good PU 2.5" Bailer and bail from 2709-2821 Tubing pressure 400 psi. Continue bailing fill while pressuring up lubricator use 2.5" bailer down to 2810' LD Lubricator and SD for night Ops pressure up well to 750 psi overnight. 07/22/2023 - Saturday 07/26/2023 - Wednesday Approved PTW and PJSM. R/u SL, P/T to 2500psi. RIH W/ 3.5"x14' pump bailer to 2778' KB, W/T 2784', POOH empty. Switch to ball bottom. RIH W/ 3.5"x14' pump bailer to 2785' KB, W/T, POOH full fluid. RIH W/ same to 2786' KB, W/T, POOH full fluid. RIH W/ 2" x 6'/ DD bailer to 2786' KB, W/T, POOH full fluid, bottom packed off with sand. RIH W/ 2.5" x 10' pump bailer to 2786' KB, W/T, POOH full fluid. Bleed well down to 600 PSI. RIH W/ 2.5" x 10' pump bailer to 2786' KB, W/T, make no hole, bleed well down to 400 PSI, W/T to 2793', POOH, empty, flapper stuck open. RIH W/ 3.5"x14' pump bailer to 2793' KB RIH W/ same to 2798' KB, W/T 2812', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2795' KB, W/T 2810', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2795' KB, W/T 2817', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2802' KB, W/T 2822', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2808' KB, W/T 2826', POOH full sand. L/d tools and Lubricator, SDFN Rig Start Date End Date 7/20/23 8/1/23 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00-00 215-100 Approved PTW and PJSM. RIH W/ 2.5"x10' pump bailer to 2820' KB, W/T 2821', POOH full wet sand. RIH W/ 2.5"x10' DD bailer to 2821' KB, W/T 2820, bleed well down to 150 PSI, tag at 2770', W/T, break through bridge, fall to 2846', make a couple passes up and down, POOH full sand. RIH W/ 3.5"x14' DD bailer, fluid level 750', tag at 2846' KB, POOH full sand. RIH W/ 3.5"x14' DD bailer to 2836' KB, pick up, run back in, tag at 2846', POOH full sand. RIH W/ 3.5"x8' DD bailer, fluid level 650', tag at 2833' KB, W/T 2841', POOH. Pressure up to 2500 PSI. Run back in, FL 700', POOH full sand. RIH W/ 2"x6' DD bailer to 2832' KB, W/T, pull up past fluid level, bleed well down to 700 PSI, run back in, tag at 2829', W/T POOH, bottom packed off with sand. Bleed well down to 250 PSI, RIH W/ 3.5"x8' DD bailer, fluid level 750', tag at 2829' KB, W/T, make no hole, pick up above fluid level, bleed tubing down to 150 PSI, RIH, tag at 2819', W/T 2844', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2839' KB, W/T 2848', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2840' KB, W/T 2848', POOH full sand. RIH W/ 3.79" G-Ring to 2840', W/T, suck, spang up, bleed tubing pressure to 200 PSI pull 15 jar licks, hold a bind at 1500# for 30 min, tubing pressure to 150 PSI, pull up to 1700# comes free, pressure up tubing to 500 PSI, slowly drift back down to 2835' KB, did not tag, POOH. Lay lubricator down, secure well head. SDFN 07/27/2023 - Thursday Approve PTW and PJSM. R/u S/L, RIH W/ 3.5"x8' DD bailer to 2802' KB, can't see spangs W/T 2813', POOH bottom full of sand, rest fluid. RIH W/ 2.5"x10' DD bailer to 2819' KB, ca RIH W/ 2.5"x10' DD bailer to 2833'KB, pick up, overpull to 2809', RIH, tag at 2840', W/T 2843', POOH full sand. RIH W/ 3.5"x8' DD bailer to 2811', W/T 2838', POOH full sand. RIH W/ 3.5"x8' DD bailer to. RIH W/ 3.5"x8' DD bailer to 2816', W/T 2834', gets stuck, pull 5 jar licks, slack off for a minute, pick up, tools appear to move up hole slightly, slack back off, repeat 3 times, flow tubing down to 150 PSI, tools move, up hole while stuck, maintain 1000# overpull, weight begins fall off at 2750', POOH fluid level is up to 950'. Pressure up tubing to 500 PSI. RIH W/ 2.5"x5' DD bailer to 2811' KB. Bleed tubing to 425 PSI, RIH W/ 2.5"x5' DD bailer to 2810' KB, W/T 2811', POOH, bottom full sand. RIH W/ 2.5"x10' pump bailer to 2810' KB, W/T 2812', POOH bottom full sand, rest fluid. RIH W/ 2.5"x10' pump bailer to 2814' KB, W/T 2820', POOH full sand. RIH W/ 2.5"x10' pump bailer to 2819' KB, W/T 2820', POOH 1/2 full sand, no fluid. RIH W/ 2.5"x10' pump bailer to 2821' KB, W/T, POOH empty. L/d Tools and Lubricator and secured well. 07/28/2023- Friday Rig Start Date End Date 7/20/23 8/1/23 Daily Operations. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00-00 215-100 08/01/2023 - Tuesday YJ arrived in Swanson, approved PTW and PJSM. R/u YJ e-line unit, M/u CCL/GR and 2-3/4" x 3' gun loaded 6spf HSC. CCL to top shot =12.5', M/u lubricator and PCE stabbed on well. P/t 250-2500psi-good. RIH made correlation pass, sent log to town confirmed on depth. SITP 662psi. Positioned CCL 2812.5' and fired gun perf A-9 sand @ 2825'-28'. Recorded pressures 5mins=651psi, 10min=650psi, 15mins=649psi, POOH L/d gun, confirmed all shots fired and bull plug was wet. M/u GPT tool and RIH, locate fluid level @ 2750'. Bleed off tbg f/644psi t/619psi and fluid level was at 2745'. Decision made to push fluid away and set CIBP above intervals. Pressured up on well to 1850psi, logged GPT tool down to perfs and confirmed no fluid level in tbg. POOH L/d GPT tool. M/u GR/CCL, setting tool and 3.5" OD CIBP, RIH set plug at 2810'. POOH L/d setting tool, bleed well from 1850 to 750psi. M/u CCL/GR and 2-3/4" x 4' gun loaded 6spf HSC. CCL to top shot =12'. RIH, correlated, sent log to town confirmed on depth. SITP 747psi, Positioned CCL at 2776', fired gun in A-9 sands 2788'-92'. Recorded pressures 5mins=710psi, 10min=670psi, 15mins=590psi, POOH L/d gun, confirmed all shots fired and bull plug was dry. RDMO YJ E-line unit and eq. Operations will monitor pressure, once pressure is stabilized, flow well <500 mcf and monitor. 07/29/2023 - Saturday Approved PTW and held PJSM. R/u SL, re-head SL, M/u 3.79" GR and braided line brush. RIH tag 2833'KB. W/t POOH. M/u 3-1/2" DD Bailer. RIH tag at 2835' bail to 2840'. POOH bailer full of sand. RIH w/same and tag 2840' W/t to 2844'. POOH. L/d Lubricator and standby for EL. Approve PTW and PJSM, MIRU YJ E-line Unit, M/u 2-3/4" GR/CCL, setting tool and 3.5" OD Big Boy Bridge Plug (LOT#3102236). CCL to CIBP =12'. M/u PCE and Lubricator on well. P/t t0250-2500psi- good. Open swab and RIH. Ran correlation pass, positioned and set top of CIBP @ 2,832'. POOH. L/d tools and secured eq. R/u SL, Begin swabbing, fluid level 575'. Swabbed from 575' to 2420'. Strapped tank at 32" approximately 28 barrels returns in tank. 07/30/2023 - Sunday Approved PTW and held PJSM. R/u SL. continued swapping well f/2820' to CIBP at 2832'. recovered a total of 33bbls. M/u 3-1/2" pump bailer, RIH tagged CIBP @ 2832'. Worked bailer POOH, L/d bailer no solids recovered. RDMO Pollard SL. Secured well. _____________________________________________________________________________________ Updated by DMA 08-02-23 SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Amt Date Status Sterling A9 2,788 2,792 2,497 2,501 48/1/23 Open Sterling A9 2,825 2,828 2,531 2,534 38/1/23 Isolated (8/1/23) Sterling A10 2,835 2,845 2,541 2,55010 7/20/23 Isolated (8/1/23) Sterling A11 2,959 2,961 2,657 2,659 28/3/22 Isolated (7/20/23) Sterling A13 3,145 3,152 2,838 2,845 77/22/22 Isolated (7/20/23) Sterling A14 3,179 3,187 2,871 2,879 86/24/22 Isolated (7/22/22) Sterling B2U 3,356 3,359 3,048 3,051 34/30/22 Isolated (4/30/22) Sterling B2L 3,417 3,421 3,108 3,112 412/3/21 Isolated (7/22/22) Sterling B3 3,446 3,450 3,138 3,142 49/3/21 Isolated (7/22/22) Sterling B4U 3,492 3,495 3,183 3,186 38/31/21 Isolated (9/1/21) Sterling B4L 3,510 3,513 3,202 3,205 38/31/21 Isolated (9/1/21) Sterling B5 3,520 3,527 3,212 3,219 78/31/21 Isolated (9/1/21) B6 (Upper)3,688 3,693 3,380 3,3855' 6/25/20 Isolated (8/30/21) B6 3,705 3,710 3,396 3,4015' 6/28/19 Isolated UB_36-9X 3,864 3,866 3,555 3,5582' 6/5/19 Isolated UB 36-9AX 3,978 3,998 3,670 3,69020' 4/25/16 Isolated UB 38-1 4,145 4,155 3,837 3,84710' 10/2/15 Isolated UB 38-4 4,218 4,223 3,910 3,9155' 10/2/15 Isolated 4,246 4,256 3,938 3,94810' 10/2/15 Isolated 4,336 4,341 4,028 4,0335' 10/2/15 Isolated OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8: Hole: 157bbls 12ppg lead cement followed by 43bbls 15.4ppg tail cement. No losses. 94bbls cement to surface 4-1/26-3/4 hole: 51.6bbls 13.5ppg lead cement followed by 38bbls 15.3ppg tail cement. 15bbl losses during job. ToC ~1,770 MD from 9/24/15 CBL 7 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor- Driven 72# / L-80 / Weld 12.347Surf 120 7-5/8Surface 29.7# / L-80 / BTC 6.875Surf 2,525 4-1/2Production 12.6# / L-80 / DWC/C HT 3.958Surf 4,466 JEWELRY DETAIL No Depth Item 1 1,981Baker Swell Packer 2 2,810CIBP (8/1/23) 3 2,832CIBP (7/29/23) 4 2,846CIBP (7/28/23) 5 2,863CIBP w/ 5 cement ToC = 2,858 MD (7/20/23) 6 3,165CIBP w/ 5 cement - ToC = 3,160 MD. (7/19/22) 7 3,348Owen X-span SC Patch: ID = 2.992. Set from 3,348-3,459 (4/30/22) 8 3,487CIBP with 20 cement ToC @ 3,467 MD (9/1/21) 9 3,638CIBP w/ 35 of cement TOC @ 3,603 (08/30/21) 10 3,700CIBP 06/25/20 11 3,780CIBP w/ 35 cement TOC @ 3,745 (06/27/19) 12 3,935CIBP w/ 35 cement TOC @ 3,900 (04/12/19) 13 4,238Model D Perm Packer, 1.97 ID 14 4,347x-nipple, 1.875 ID 15 4,25610K Dual Ceramic Disc, (intact), 1.995 ID 16 4,258WLEG, 1.995 ID FISH DETAIL >3,423 5/1/22 Fish left in hole. Approximately 50' of 9/32" wireline, Perf Gun Assembly: one gun live and 1 gun spent. OAL. 23.3' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230821 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU F-81 50029229590000 200066 7/30/2023 YELLOW JACKET Cut MPU F-81 50029229590000 200066 8/6/2023 YELLOW JACKET Perf SRU 213-15 50133206520000 215100 7/29/2023 YELLOW JACKET Plug/Perf/GPT Please include current contact information if different from above. T37949 T37949 T37950 8/21/2023 YELLOWSRU 213-15 50133206520000 215100 7/29/2023 JACKET Plug/Perf/GPT Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.21 10:19:38 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/31/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230731 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205055 7/22/2023 YELLOW JACKET SCBL KU 22-6X 50133205800000 208135 6/23/2023 HALLIBURTON EPX KU 22-6X 50133205800000 208135 6/23/2023 HALLIBURTON MFC MPU F-09 50029227730000 197104 7/22/2023 YELLOW JACKET PERF SRU 213-15 50133206520000 215100 7/20/2023 YELLOW JACKET GPT/PLUG/PERF Please include current contact information if different from above. T37902PTD:205-054 T37903 T37903 T37904 T37905YELLOWSRU 213-15 50133206520000 215100 7/20/2023 GPT/PLUG/PERFJACKET Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:13:43 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,470'3,423' (fish) Casing Collapse Structural Conductor Surface 4,790 psi Intermediate Production 7,500 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Chad Helgeson, Operations Engineer chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size: N/A N/A May 24, 2023 Baker Swell Pkr; Model D Perm Pkr; N/A 1,981' MD / 1,807' TVD; 4,238' MD / 3,930' TVD; N/A See Schematic See Schematic N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028406 215-100 50-133-20652-00-00 Swanson River Sterling-Up Beluga Gas Same CO 716A Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Swanson River Unit (SRU) 213-15 Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 4,162'3,160'2,853'~898 psi See Schematic MD 6,890 psi 120' 2,265' 120' 2,525' Perforation Depth MD (ft): 4,466'4-1/2" 13-3/8" 7-5/8" 120' 2,525' 8,430 psi4,158'4,466' m n P s t _ 66 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-277 By Grace Christianson at 8:57 am, May 11, 2023 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361), ou=Users Date: 2023.05.10 17:20:06 -08'00' Noel Nocas (4361) DSR-5/12/23BJM 6/5/23 10-404 SFD 5/18/2023GCW 06/05/2023JLC 6/5/2023 06/05/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.05 14:23:30 -08'00' RBDMS JSB 060623 Well: SRU 213-15 5/10/23 Well Name: SRU 213-15 API Number: 50-133-20652-00-00 Current Status: Gas Producer Permit to Drill Number: 215-100 First Call Engineer: Chad Helgeson (907) 777-8504 (O) (907) 229-4824 (C) Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C) Max. Expected BHP: ~1,152 psi @ 2550’ TVD Based on 0.452 psi/ft Max. Potential Surface Pressure ~898 psi @ 2550’ TVD Based on 0.1 psi/ft to surface Well Summary SRU 213-15 recently stopped producing, from current open Sterling sands. The well still has several unshot Sterling sands, so additional perfs are proposed. All Sterling sands fall within the A-8 or below, keeping all within the existing Sterling Pool/PA. The goal of this project is to plug back existing Sterling sands and perforate additional Sterling sands to increase production from the well. Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max Inclination = 33 degrees sail angle from 1,000’-2,600’ MD x Recent history o 5/3/22 SL tagged and bailed hard clay to 2,881’ o 7/19/22 EL set CIBP w 5’ of cement @ 3,160’ o 8/3/22 EL perforated A11 Sand (2,959-2,961’) E-Line Perf 1. Review all approved COAs (BLM & AOGCC) 2. MIRU E-line and pressure control equipment. PT lubricator to 250psi low / 1,500 psi High 3. PU CIBP, RIH and set at 2,877’ or as deep as possible below 2,857’, without a fill cleanout. (SL tag was 2,881 KB, no collars between 2,844’ & 2,882’) a. If fluid in well above perfs, use SL to swab well down. 4. Ops pressure up well to 700 psi after swabbing well. 5. PU and RIH with perf gun 6. Perforate Sterling sands per RE/Geo from ±2788 – ±2857 MD individually and tested. Zones will be commingled as needed per reservoir engineer. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) Sterling A9 ±2788 ±2828 ±2497 ±2534 ±40 Sterling A10 ±2834 ±2857 ±2554 ±2561 ±23 a. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. b. Record initial and 5/10/15 minute tubing pressures after firing All Sterling sands fall within the A-8 or below, keeping all within the existing Sterling Pool/PA. Well: SRU 213-15 5/10/23 7. RD E-Line Unit and turn well over to production 8. Operations to flow well and test zones E-line Procedure (Contingency) If any zone produces sand and/or water or needs isolated: 1. MIRU Eline 2. Pressure test equipment to 3,000 psi High/250 psi Low 3. Eline run PT to find fluid level (Pressure up with GL gas if needed) 4. Push fluid below perfs (verify fluid depth with PT tool) 5. PU 4-1/2” CIBP RIH and set above perfs a. Note: there is minimal room between sets of perfs for cement. Coil tubing procedure (Contingency) If plug does not get below proposed perfs and SL cannot bail enough fill: a. MIRU Fox Coiled Tubing Unit, PT BOPE to 3,000 psi High/250 psi Low b. Provide AOGCC 24hrs notice of BOP test c. PU CT jet nozzle and cleanout well to top of open perfs. d. POOH with coil e. RDMO coil tubing f. Complete Eline as necessary Attachments: 1. Current schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram _____________________________________________________________________________________ Updated by CAH 05-10-23 PROPOSED Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 PERFORATION DETAIL Zone Top MD Btm MD Top TVD Btm TVD Amt Date Status Sterling A-9 ±2788 ±2828 ±2497 ±2534 ±40 TBD Proposed Sterling A-10 ±2834 ±2857 ±2554 ±2561 ±23 TBD Proposed Sterling A11 2,959’2,961’2,657’2,659’2’8/3/22 Isolated Sterling A13 3,145’3,152’2,838’2,845’7’7/22/22 Isolated Sterling A14 3,179’3,187’2,871’2,879’8’6/24/22 Isolated (7/22/22) Sterling B2U 3,356’3,359’3,048’3,051’3’4/30/2022 Isolated (4/30/22) Sterling B2L 3,417’3,421’3,108’3,112’4’12/3/2021 Isolated (7/22/22) Sterling B3 3,446’3,450’3,138’3,142’4’9/3/2021 Isolated (7/22/22) Sterling B4U 3,492’3,495’3,183’3,186’3’8/31/2021 Isolated (9/1/21) Sterling B4L 3,510’3,513’3,202’3,205’3’8/31/2021 Isolated (9/1/21) Sterling B5 3,520’3,527’3,212’3,219’7’8/31/2021 Isolated (9/1/21) B6 (Upper)3,688’3,693’3,380’3,385’5'6/25/2020 Isolated (8/30/21) B6 3,705’3,710’3,396’3,401’5'6/28/2019 Isolated UB_36-9X 3,864’3,866’3,555’3,558’2'6/5/2019 Isolated UB 36-9AX 3,978’3,998’3,670’3,690’20'4/25/2016 Isolated UB 38-1 4,145’4,155’3,837’3,847’10'10/2/2015 Isolated UB 38-4 4,218’4,223’3,910’3,915’5'10/2/2015 Isolated 4,246’4,256’3,938’3,948’10'10/2/2015 Isolated 4,336’4,341’4,028’4,033’5'10/2/2015 Isolated OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8: Hole: 157bbls 12ppg lead cement followed by 43bbls 15.4ppg tail cement. No losses. 94bbls cement to surface 4-1/2”6-3/4” hole: 51.6bbls 13.5ppg lead cement followed by 38bbls 15.3ppg tail cement. 15bbl losses during job. ToC ~1,770’ MD from 9/24/15 CBL 7 4 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor- Driven 72# / L-80 / Weld 12.347”Surf 120’ 7-5/8”Surface 29.7# / L-80 / BTC 6.875”Surf 2,525’ 4-1/2”Production 12.6# / L-80 / DWC/C HT 3.958”Surf 4,466’ JEWELRY DETAIL No Depth Item 1 1,981’Baker Swell Packer 2A ±2,877’CIBP 2 3,165’CIBP with 5’ cement - ToC = 3160’ MD. (7/19/22) 3 3,348’Owen X-span SC Patch: ID = 2.992”. Set from 3,348-3,459’ 4/30/22 4 3,487’CIBP with 20’ cement – ToC @ 3467’ MD (9/1/21) 5 3,638’CIBP w/ 35’ of cement – TOC @ 3,603’ 08/30/21 6 3,700’CIBP 06/25/20 7 3,780’CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 8 3,935’CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 9 4,238’Model D Perm Packer, 1.97” ID 10 4,347’x-nipple, 1.875” ID 11 4,256’10K Dual Ceramic Disc, (intact), 1.995 ID 12 4,258’WLEG, 1.995” ID FISH DETAIL >3,423’ 5/1/22 Fish left in hole. Approximately 50' of 9/32" wireline, Perf Gun Assembly: one gun live and 1 gun spent. OAL. 23.3' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG MPU I-17 50029232120000 204098 7/19/2022 Yellowjacket TUBING CUT CLU 05RD 50133204740100 215160 7/21/2022 Yellowjacket PLUG CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Please include current contact information if different from above. By Meredith Guhl at 8:52 am, Nov 23, 2022 T37295 T37295 T37295 T37296 T37297 T37297 T37298 T37299 T37300 T37301 T37302 SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:08:15 -09'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220928 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 07A 501332028401 214060 7/12/2022 AK E-Line CIBP GPT BCU 18RD 501332058401 222033 7/13/2022 AK E-Line Perf BCU 18RD 501332058401 222033 7/16/2022 AK E-Line GPT Perf BCU 18RD 501332058401 222033 7/23/2022 AK E-Line GPT CIBP Perf BRU 212-24 502832003700 172015 6/27/2022 AK E-Line CBL BRU 212-24 502832003700 172015 7/5/2022 AK E-Line CIBP CBL TBG END 1-45 500292199100 189124 7/23/2022 AK E-Line Perf END 4-02 500292178900 188022 7/21/2022 AK E-Line Perf HVB B-16 502312004000 212133 6/23/2022 AK E-Line Drift, Plug, Cement IRU 241-01 502832018400 221076 8/5/2022 AK E-Line CBL IRU 241-01 502832018400 221076 8/9/2022 AK E-Line Perf Kalotsa 6 501332068500 219114 7/16/2022 AK E-Line Perf KTU 24-06H 501332049000 199073 7/15/2022 AK E-Line GPT Perf MPU S-34 500292317100 203130 7/5/2022 AK E-Line Drift PBU F-26C 500292198703 213045 8/4/2022 AK E-Line Patch/LDL SRU 213-15 501332065200 215100 8/3/2022 AK E-Line GPT Perf Please include current contact information if different from above. 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ϭ͘ƵƌƌĞŶƚƐĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇZZϬϱͲϮϰͲϮϮ ^,Dd/ tĞůů͗^ZhϮϭϯͲϭϱ W/η͗ϱϬͲϭϯϯͲϮϬϲϱϮͲϬϬͲϬϬ Wd͗ϮϭϱͲϭϬϬ KWE,K>ͬDEdd/> ϳͲϱͬϴΗϵͲϳͬϴ͗,ŽůĞ͗ϭϱϳďďůƐϭϮƉƉŐůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďǇϰϯďďůƐϭϱ͘ϰƉƉŐƚĂŝůĐĞŵĞŶƚ͘EŽůŽƐƐĞƐ͘ϵϰďďůƐ ĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ ϰͲϭͬϮ͟ϲͲϯͬϰ͟ŚŽůĞ͗ϱϭ͘ϲďďůƐϭϯ͘ϱƉƉŐůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďǇϯϴďďůƐϭϱ͘ϯƉƉŐƚĂŝůĐĞŵĞŶƚ͘ϭϱďďůůŽƐƐĞƐ ĚƵƌŝŶŐũŽď͘dŽΕϭ͕ϳϳϬ͛DĨƌŽŵϵͬϮϰͬϭϱ> ϳ ϰ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϯͲϯͬϴΗŽŶĚƵĐƚŽƌͲ ƌŝǀĞŶϳϮηͬ>ͲϴϬͬtĞůĚϭϮ͘ϯϰϳ͟^ƵƌĨϭϮϬ͛ ϳͲϱͬϴ͟^ƵƌĨĂĐĞϮϵ͘ϳηͬ>ͲϴϬͬdϲ͘ϴϳϱ͟^ƵƌĨϮ͕ϱϮϱ͛ ϰͲϭͬϮ͟WƌŽĚƵĐƚŝŽŶϭϮ͘ϲηͬ>ͲϴϬͬtͬ,dϯ͘ϵϱϴ͟^ƵƌĨϰ͕ϰϲϲ͛ WZ&KZd/KEd/> ŽŶĞdŽƉDƚŵDdŽƉdsƚŵdsŵƚĂƚĞ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐϮhϯ͕ϯϱϲ͛ϯ͕ϯϱϵ͛ϯ͕Ϭϰϴ͛ϯ͕Ϭϱϭ͛ϯ͛ϰͬϯϬͬϮϬϮϮ/ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐϮ>ϯ͕ϰϭϳ͛ϯ͕ϰϮϭ͛ϯ͕ϭϬϴ͛ϯ͕ϭϭϮϰ͛ϭϮͬϯͬϮϬϮϭKƉĞŶ ^ƚĞƌůŝŶŐϯϯ͕ϰϰϲ͛ϯ͕ϰϱϬ͛ϯ͕ϭϯϴ͛ϯ͕ϭϰϮ͛ϰ͛ϵͬϯͬϮϬϮϭKƉĞŶ ^ƚĞƌůŝŶŐϰhϯ͕ϰϵϮ͛ϯ͕ϰϵϱ͛ϯ͕ϭϴϯ͛ϯ͕ϭϴϲ͛ϯ͛ϴͬϯϭͬϮϬϮϭ/ƐŽůĂƚĞĚ;ϵͬϭͬϮϭͿ ^ƚĞƌůŝŶŐϰ>ϯ͕ϱϭϬ͛ϯ͕ϱϭϯ͛ϯ͕ϮϬϮ͛ϯ͕ϮϬϱ͛ϯ͛ϴͬϯϭͬϮϬϮϭ/ƐŽůĂƚĞĚ;ϵͬϭͬϮϭͿ ^ƚĞƌůŝŶŐϱϯ͕ϱϮϬ͛ϯ͕ϱϮϳ͛ϯ͕ϮϭϮ͛ϯ͕Ϯϭϵ͛ϳ͛ϴͬϯϭͬϮϬϮϭ/ƐŽůĂƚĞĚ;ϵͬϭͬϮϭͿ ϲ;hƉƉĞƌͿϯ͕ϲϴϴ͛ϯ͕ϲϵϯ͛ϯ͕ϯϴϬ͛ϯ͕ϯϴϱ͛ϱΖϲͬϮϱͬϮϬϮϬ/ƐŽůĂƚĞĚ;ϴͬϯϬͬϮϭͿ ϲϯ͕ϳϬϱ͛ϯ͕ϳϭϬ͛ϯ͕ϯϵϲ͛ϯ͕ϰϬϭ͛ϱΖϲͬϮϴͬϮϬϭϵ/ƐŽůĂƚĞĚ hͺϯϲͲϵyϯ͕ϴϲϰ͛ϯ͕ϴϲϲ͛ϯ͕ϱϱϱ͛ϯ͕ϱϱϴ͛ϮΖϲͬϱͬϮϬϭϵ/ƐŽůĂƚĞĚ hϯϲͲϵyϯ͕ϵϳϴ͛ϯ͕ϵϵϴ͛ϯ͕ϲϳϬ͛ϯ͕ϲϵϬ͛ϮϬΖϰͬϮϱͬϮϬϭϲ/ƐŽůĂƚĞĚ hϯϴͲϭϰ͕ϭϰϱ͛ϰ͕ϭϱϱ͛ϯ͕ϴϯϳ͛ϯ͕ϴϰϳ͛ϭϬΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ hϯϴͲϰ ϰ͕Ϯϭϴ͛ϰ͕ϮϮϯ͛ϯ͕ϵϭϬ͛ϯ͕ϵϭϱ͛ϱΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ ϰ͕Ϯϰϲ͛ϰ͕Ϯϱϲ͛ϯ͕ϵϯϴ͛ϯ͕ϵϰϴ͛ϭϬΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ ϰ͕ϯϯϲ͛ϰ͕ϯϰϭ͛ϰ͕ϬϮϴ͛ϰ͕Ϭϯϯ͛ϱΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϭ͕ϵϴϭ͛ĂŬĞƌ^ǁĞůůWĂĐŬĞƌ ϭĂϯ͕ϯϰϴ͛KǁĞŶyͲƐƉĂŶ^WĂƚĐŚ͗/сϮ͘ϵϵϮ͘͟^ĞƚĨƌŽŵϯ͕ϯϰϴͲϯ͕ϰϱϵ͛ϰͬϯϬͬϮϮ Ϯϯ͕ϰϴϳ͛/WǁŝƚŚϮϬ͛ĐĞŵĞŶƚʹdŽΛϯϰϲϳ͛D;ϵͬϭͬϮϭͿ ϮĂϯ͕ϲϯϴ͛/Wǁͬϯϱ͛ŽĨĐĞŵĞŶƚʹdKΛϯ͕ϲϬϯ͛ϬϴͬϯϬͬϮϭ ϯϯ͕ϳϬϬ͛/WϬϲͬϮϱͬϮϬ ϰϯ͕ϳϴϬ͛/Wǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϳϰϱ͛ϬϲͬϮϳͬϭϵ ϱϯ͕ϵϯϱ͛/Wǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϵϬϬϬϰͬϭϮͬϭϵ ϲϰ͕Ϯϯϴ͛DŽĚĞůWĞƌŵWĂĐŬĞƌ͕ϭ͘ϵϳ͟/ ϳϰ͕ϯϰϳ͛ǆͲŶŝƉƉůĞ͕ϭ͘ϴϳϱ͟/ ϴϰ͕Ϯϱϲ͛ϭϬ<ƵĂůĞƌĂŵŝĐŝƐĐ͕;ŝŶƚĂĐƚͿ͕ϭ͘ϵϵϱ/ ϵϰ͕Ϯϱϴ͛t>'͕ϭ͘ϵϵϱ͟/ &/^,d/>хϯ͕ϰϮϯ͛ϱͬϭͬϮϮ &ŝƐŚůĞĨƚŝŶŚŽůĞ͘ƉƉƌŽǆŝŵĂƚĞůǇϱϬΖŽĨϵͬϯϮΗǁŝƌĞůŝŶĞ͕WĞƌĨ'ƵŶƐƐĞŵďůǇ͗ŽŶĞŐƵŶůŝǀĞĂŶĚϭŐƵŶ ƐƉĞŶƚ͘K>͘Ϯϯ͘ϯΖ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚďǇDϬϱͲϮϰͲϮϮ WZKWK^ tĞůů͗^ZhϮϭϯͲϭϱ W/η͗ϱϬͲϭϯϯͲϮϬϲϱϮͲϬϬͲϬϬ Wd͗ϮϭϱͲϭϬϬ KWE,K>ͬDEdd/> ϳͲϱͬϴΗϵͲϳͬϴ͗,ŽůĞ͗ϭϱϳďďůƐϭϮƉƉŐůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďǇϰϯďďůƐϭϱ͘ϰƉƉŐƚĂŝůĐĞŵĞŶƚ͘EŽůŽƐƐĞƐ͘ϵϰďďůƐ ĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ ϰͲϭͬϮ͟ϲͲϯͬϰ͟ŚŽůĞ͗ϱϭ͘ϲďďůƐϭϯ͘ϱƉƉŐůĞĂĚĐĞŵĞŶƚĨŽůůŽǁĞĚďǇϯϴďďůƐϭϱ͘ϯƉƉŐƚĂŝůĐĞŵĞŶƚ͘ϭϱďďůůŽƐƐĞƐ ĚƵƌŝŶŐũŽď͘dŽΕϭ͕ϳϳϬ͛DĨƌŽŵϵͬϮϰͬϭϱ> ϳ ϰ ^/E'd/> ^ŝǌĞdǇƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵ ϭϯͲϯͬϴΗŽŶĚƵĐƚŽƌͲ ƌŝǀĞŶϳϮηͬ>ͲϴϬͬtĞůĚϭϮ͘ϯϰϳ͟^ƵƌĨϭϮϬ͛ ϳͲϱͬϴ͟^ƵƌĨĂĐĞϮϵ͘ϳηͬ>ͲϴϬͬdϲ͘ϴϳϱ͟^ƵƌĨϮ͕ϱϮϱ͛ ϰͲϭͬϮ͟WƌŽĚƵĐƚŝŽŶϭϮ͘ϲηͬ>ͲϴϬͬtͬ,dϯ͘ϵϱϴ͟^ƵƌĨϰ͕ϰϲϲ͛ WZ&KZd/KEd/> ŽŶĞdŽƉDƚŵDdŽƉdsƚŵdsŵƚĂƚĞ^ƚĂƚƵƐ ^ƚĞƌůŝŶŐцϮ͕ϲϲϵ͛цϯ͕ϵϳϬ͛цϮ͕ϯϵϬ͛цϮ͕ϵϲϮ͛цϲϬϭ͛WƌŽƉŽƐĞĚd ^ƚĞƌůŝŶŐϮhϯ͕ϯϱϲ͛ϯ͕ϯϱϵ͛ϯ͕Ϭϰϴ͛ϯ͕Ϭϱϭ͛ϯ͛ϰͬϯϬͬϮϬϮϮ/ƐŽůĂƚĞĚ ^ƚĞƌůŝŶŐϮ>ϯ͕ϰϭϳ͛ϯ͕ϰϮϭ͛ϯ͕ϭϬϴ͛ϯ͕ϭϭϮ͛ϰ͛ϭϮͬϯͬϮϬϮϭKƉĞŶ ^ƚĞƌůŝŶŐϯϯ͕ϰϰϲ͛ϯ͕ϰϱϬ͛ϯ͕ϭϯϴ͛ϯ͕ϭϰϮ͛ϰ͛ϵͬϯͬϮϬϮϭKƉĞŶ ^ƚĞƌůŝŶŐϰhϯ͕ϰϵϮ͛ϯ͕ϰϵϱ͛ϯ͕ϭϴϯ͛ϯ͕ϭϴϲ͛ϯ͛ϴͬϯϭͬϮϬϮϭ/ƐŽůĂƚĞĚ;ϵͬϭͬϮϭͿ ^ƚĞƌůŝŶŐϰ>ϯ͕ϱϭϬ͛ϯ͕ϱϭϯ͛ϯ͕ϮϬϮ͛ϯ͕ϮϬϱ͛ϯ͛ϴͬϯϭͬϮϬϮϭ/ƐŽůĂƚĞĚ;ϵͬϭͬϮϭͿ ^ƚĞƌůŝŶŐϱϯ͕ϱϮϬ͛ϯ͕ϱϮϳ͛ϯ͕ϮϭϮ͛ϯ͕Ϯϭϵ͛ϳ͛ϴͬϯϭͬϮϬϮϭ/ƐŽůĂƚĞĚ;ϵͬϭͬϮϭͿ ϲ;hƉƉĞƌͿϯ͕ϲϴϴ͛ϯ͕ϲϵϯ͛ϯ͕ϯϴϬ͛ϯ͕ϯϴϱ͛ϱΖϲͬϮϱͬϮϬϮϬ/ƐŽůĂƚĞĚ;ϴͬϯϬͬϮϭͿ ϲϯ͕ϳϬϱ͛ϯ͕ϳϭϬ͛ϯ͕ϯϵϲ͛ϯ͕ϰϬϭ͛ϱΖϲͬϮϴͬϮϬϭϵ/ƐŽůĂƚĞĚ hͺϯϲͲϵyϯ͕ϴϲϰ͛ϯ͕ϴϲϲ͛ϯ͕ϱϱϱ͛ϯ͕ϱϱϴ͛ϮΖϲͬϱͬϮϬϭϵ/ƐŽůĂƚĞĚ hϯϲͲϵyϯ͕ϵϳϴ͛ϯ͕ϵϵϴ͛ϯ͕ϲϳϬ͛ϯ͕ϲϵϬ͛ϮϬΖϰͬϮϱͬϮϬϭϲ/ƐŽůĂƚĞĚ hϯϴͲϭϰ͕ϭϰϱ͛ϰ͕ϭϱϱ͛ϯ͕ϴϯϳ͛ϯ͕ϴϰϳ͛ϭϬΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ hϯϴͲϰ ϰ͕Ϯϭϴ͛ϰ͕ϮϮϯ͛ϯ͕ϵϭϬ͛ϯ͕ϵϭϱ͛ϱΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ ϰ͕Ϯϰϲ͛ϰ͕Ϯϱϲ͛ϯ͕ϵϯϴ͛ϯ͕ϵϰϴ͛ϭϬΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ ϰ͕ϯϯϲ͛ϰ͕ϯϰϭ͛ϰ͕ϬϮϴ͛ϰ͕Ϭϯϯ͛ϱΖϭϬͬϮͬϮϬϭϱ/ƐŽůĂƚĞĚ :t>Zzd/> EŽĞƉƚŚ/ƚĞŵ ϭϭ͕ϵϴϭ͛ĂŬĞƌ^ǁĞůůWĂĐŬĞƌ ϭĂϯ͕ϯϰϴ͛KǁĞŶyͲƐƉĂŶ^WĂƚĐŚ͗/сϮ͘ϵϵϮ͘͟^ĞƚĨƌŽŵϯ͕ϯϰϴͲϯ͕ϰϱϵ͛ϰͬϯϬͬϮϮ Ϯϯ͕ϰϴϳ͛/WǁŝƚŚϮϬ͛ĐĞŵĞŶƚʹdŽΛϯϰϲϳ͛D;ϵͬϭͬϮϭͿ ϮĂϯ͕ϲϯϴ͛/Wǁͬϯϱ͛ŽĨĐĞŵĞŶƚʹdKΛϯ͕ϲϬϯ͛ϬϴͬϯϬͬϮϭ ϯϯ͕ϳϬϬ͛/WϬϲͬϮϱͬϮϬ ϰϯ͕ϳϴϬ͛/Wǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϳϰϱ͛ϬϲͬϮϳͬϭϵ ϱϯ͕ϵϯϱ͛/Wǁͬϯϱ͛ĐĞŵĞŶƚʹdKΛϯ͕ϵϬϬϬϰͬϭϮͬϭϵ ϲϰ͕Ϯϯϴ͛DŽĚĞůWĞƌŵWĂĐŬĞƌ͕ϭ͘ϵϳ͟/ ϳϰ͕ϯϰϳ͛ǆͲŶŝƉƉůĞ͕ϭ͘ϴϳϱ͟/ ϴϰ͕Ϯϱϲ͛ϭϬ<ƵĂůĞƌĂŵŝĐŝƐĐ͕;ŝŶƚĂĐƚͿ͕ϭ͘ϵϵϱ/ ϵϰ͕Ϯϱϴ͛t>'͕ϭ͘ϵϵϱ͟/ &/^,d/>хϯ͕ϰϮϯ͛ϱͬϭͬϮϮ &ŝƐŚůĞĨƚŝŶŚŽůĞ͘ƉƉƌŽǆŝŵĂƚĞůǇϱϬΖŽĨϵͬϯϮΗǁŝƌĞůŝŶĞ͕WĞƌĨ'ƵŶƐƐĞŵďůǇ͗ŽŶĞŐƵŶůŝǀĞĂŶĚϭŐƵŶ ƐƉĞŶƚ͘K>͘Ϯϯ͘ϯΖ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 213-15 (PTD 215-100) PATCH 4/30/2022 Please include current contact information if different from above. PTD:215-100 T36614 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.17 09:24:13 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/10/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 213-15 (PTD 215-100) GPT/PERF 4/08/2022 Please include current contact information if different from above. PTD:215-100 T36592 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 10:21:37 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Karson Kozub - (C) To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC) Cc:Juanita Lovett;Donna Ambruz;Cole Bartlewski Subject:Fox CTU-8 BOPE test report SRU 213-15 (PTD 215-100) (Sundry 322-208) Date:Thursday, April 28, 2022 7:43:27 AM Attachments:Fox 8 4-26-22.xlsx Some people who received this message don't often get email from kkozub@hilcorp.com. Learn why this is important Good Morning, Attached is the BOPE test report for SRU 213-15 (Sundry 322-208) Regards, Karson Kozub Mobile: +1 (907) 570-1801 kkozub@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 6ZDQVRQ5LYHU8QLW 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:8 DATE: 4/26/22 Rig Rep.: Rig Phone: (907)887-1766 Operator: Op. Phone:(907)632-4113 Rep.: E-Mail Well Name: PTD #2151000 Sundry #322-208 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:N/A Valves:250/3500 MASP:1106 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 0NA Standing Order Posted NA Misc.NA Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 N/A NA Pit Level Indicators NA NA #1 Rams 1 1.75" BS P Flow Indicator NA NA #2 Rams 1 1.75" PS P Meth Gas Detector NA NA #3 Rams 0 N/A NA H2S Gas Detector NA NA #4 Rams 0 N/A NA MS Misc 0NA #5 Rams 0 N/A NA #6 Rams 0 N/A NA Quantity Test Result Choke Ln. Valves 2 2"P Inside Reel valves 1P HCR Valves 0 N/A NA Kill Line Valves 2 2"P Check Valve 0 N/A NA ACCUMULATOR SYSTEM: BOP Misc 0 N/A NA Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)2400 P Quantity Test Result 200 psi Attained (sec)4 P No. Valves 5P Full Pressure Attained (sec)16 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): N/A NA CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.0 Hours Repair or replacement of equipment will be made within N/A days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 4/24/22 @14:09 Waived By Test Start Date/Time:4/25/2022 12:00 (date) (time)Witness Test Finish Date/Time:4/25/2022 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Fox Accumulator precharge pressure 1400 psi Terence Rais Hilcorp Alaska Karson Kozub SRU 213-15 Test Pressure (psi): kkozub@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0426_BOP_Fox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signing and returning one copy of this transmittal Received By: Date: DATE: 1/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 213-15 (PTD 215-100) GPT- PERF 12/03/2021 Please include current contact information if different from above. 37' (6HW Received By: 01/12/2022 By Abby Bell at 10:50 am, Jan 12, 2022 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): 4,470'N/A Casing Collapse Structural Conductor Surface 4,790 psi Intermediate Production 7,500 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Ryan Rupert, Operations Engineer Contact Email:ryan.rupert@hilcorp.com Contact Phone: 907-777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 2,525' 4,466' Perforation Depth MD (ft): 4,466' 13-3/8" 7-5/8" 120'120' 2,525' 4,158'4-1/2" Length Size N/A TVD Burst N/A 8,430 psi MD 6,890 psi 120' 2,265' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028406 215-100 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 50-133-20652-00-00 Hilcorp Alaska LLC Swanson River / Sterling-Upper Beluga Gas Pool CO 716 and CO 716.001 Swanson River Unit (SRU) 213-15 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: Baker Swell Pkr; Model D Perm Pkr; N/A 1,981' MD / 1,807' TVD; 4,238' MD / 3,930' TVD; N/A 3,446 - 3,450 3,138 - 3,142 12/1/2021 N/A 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dan Marlowe, ASC Team Operations Manager, 907-283-1329 4,160' 3,467' 3,159' ~1,106 psi See schematic ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:41 pm, Nov 19, 2021 321-599 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.19 11:46:07 -09'00' Dan Marlowe (1267) CO 716A BJM 11/23/21 SFD 11/19/2021 DSR-11/22/21 10-404 SFD 11/19/2021dts 11/24/2021 11/24/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.24 08:55:59 -09'00' RBDMS HEW 11/24/2021 Well: SRU 213-15 Well Name:SRU 213-15 API Number:50-133-20652-00-00 Current Status:Gas Producer Leg:N/A Regulatory Contact:Donna Ambruz 777-8305 Permit to Drill Number:215-100 First Call Engineer:Ryan Rupert (907) 777-8503 (O) (907) 301-1736 (C) Second Call Engineer:Jake Flora (720) 988-5375 (C) Max. Expected BHP:~1,421 psi @ 3,142’ TVD Based on 0.452 psi/ft to deepest open sand (B3) Max. Potential Surface Pressure ~ 1,106 psi Based on 0.1 psi/ft to surface Well Summary SRU 213-15 has been flowing at <400mcfd since the plug/perf in Sept-2021. The well has several unshot Sterling sands. The goal of this project is to perforate additional Sterling sands to increase production from the well. Notes Regarding Wellbore Condition x Min ID = 3.833” (4-1/2” drift ID) x Max Inclination = 33 degrees sail angle from 1000’-2600’ MD x Recent history o 9/2/21: 3.71” CIBP had many tags on the way down to 3487’ MD (but ultimately made it down) 2-7/8” x 4’ perf gun went down to 3450’ MD with no issues o 8/30/21: 3.50” CIBP RIH and set at 3638’ MD no issues 2-7/8” x 20’ perf gun BHA went down to 3527’ MD with no issues o perforate additional Sterling sands t Well: SRU 213-15 E-Line Perf 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2,500 psi High 3. RIH W/ GPT tool and CIBP 4. Find FL with GPT 5. RU gas lift gas.(May omit this plug initially and keep B3 open. TBD based on production at the time) a) Push water back into formation b) Use GPT tool to confirm water level is below interval to perf c) Consult OE for pressure to leave on well for perforating 6. Once fluid level is below interval to isolate, set 4-1/2” CIBP at ±3435’ MD (Hilcorp is requesting a variance to dump bail no cement on top of this plug. See below for more details)(May omit this plug initially and keep B3 open. TBD based on production at the time) 7. POOH and rig up perf gun (Likely 2-7/8” – 3-3/8” 4-6 spf) 8. Perforate the sands listed in the table below, per Geo/RE. Sand Perforation Top (MD) Perforation Bottom (MD) Perforation Top (TVD) Perforation Bottom (TVD) Total Footage (MD) Sterling A8 ±2669 ±2695 ±2390 ±2412 ±26 Sterling A9 ±2785 ±2831 ±2495 ±2536 ±46 Sterling A10 ±2835 ±2856 ±2540 ±2561 ±21 Sterling A11 ±2957 ±2987 ±2656 ±2684 ±30 Sterling A13 ±3145 ±3152 ±2838 ±2845 ±7 Sterling A14 ±3173 ±3188 ±2866 ±2880 ±15 Sterling A15 ±3216 ±3230 ±2908 ±2921 ±14 Sterling B1 ±3258 ±3270 ±2950 ±2962 ±12 Sterling B2U ±3343 ±3362 ±3035 ±3053 ±19 Sterling B2L ±3417 ±3421 ±3108 ±3112 ±4 Consult with OE for what WHP’s to use. May be shot while flowing Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a.Use Gamma/CCL to correlate. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo between each perf interval: i. Sarah King (Geo): 970-274-9398 ii. Meredyth Richards (RE): 907-777-8430 9. RD E-Line Unit and turn well over to production. Contingency EL Plug or Patch 1. MIRU E-line, PT lubricator to 250 psi low / 2,500 psi high 2. RIH W/ GPT tool and find fluid level 3. RU gas lift gas a. Push water back into formation b. Use GPT tool to confirm water level is below interval to perf c. Consult OE for pressure to leave on well for perforating 4. Once fluid level is below interval to isolate, MU 4-1/2” patch or plug (Hilcorp is requesting a variance to dump bail no cement on top of this plug. See below for more details) Well: SRU 213-15 5. RIH and set plug or patch per OE. 6. If plug, set per table below, and dump bail cement according to table below as well. 7. RD E-Line Unit and turn well over to production. If additional CIBP’s are necessary per the above contingency, plug set depth will be ±50’ above the existing top perf, and capped with 35’ of cement per BLM regulations. Many of the intervals between sands don’t have enough space to accommodate these distances. Variance request: Hilcorp requests a variance to Onshore Order #2 Section G, 2. Proposed plug set depths and ToC depth are listed in table below. Set depths are approximate, and designed to ensure isolation between intervals, while not encroaching on perf intervals above. Top (MD) Bottom (MD) Distance between perfs Requested Plug set depth distance above perfs Requested ToC height of cement Rathole Sterling A8 ±2669 ±2695 ±90 ±2770 ±15 ±2735 35 ±40 Sterling A9 ±2785 ±2831 ±4 ±2833 ±2 n/a 0±2 Sterling A10 ±2835 ±2856 ±101 ±2907 ±50 ±2872 35 ±16 Sterling A11 ±2957 ±2987 ±158 ±3095 ±50 ±3060 35 ±73 Sterling A13 ±3145 ±3152 ±21 ±3165 ±8 n/a 0±13 Sterling A14 ±3173 ±3188 ±28 ±3205 ±11 n/a 0±17 Sterling A15 ±3216 ±3230 ±28 ±3245 ±13 n/a 0±15 Sterling B1 ±3258 ±3270 ±73 ±3330 ±13 ±3295 35 ±25 Sterling B2U ±3343 ±3362 ±55 ±3410 ±7 ±3375 35 ±13 Sterling B2L ±3417 ±3421 ±25 ±3435 ±11 n/a 0±14 Sterling B3 ±3446 ±3450 Well: SRU 213-15 Attachments: 1. Current schematic 2. Proposed Schematic _____________________________________________________________________________________ Updated by CRR 11-1-2021 SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8: Hole: 157bbls 12ppg lead cement followed by 43bbls 15.4ppg tail cement. No losses. 94bbls cement to surface 4-1/2”6-3/4” hole: 51.6bbls 13.5ppg lead cement followed by 38bbls 15.3ppg tail cement. 15bbl losses during job.ToC ~1,770’ MD from 9/24/15 CBL TD = 4,470’ MD / 4,162‘ TVD 1 RKB: MSL = 18.90’ 4-1/2” 1 3,821’ 4,186’ 13-3/8” 7-5/8” 2,932’ PBTD = 3,467’ MD / 3,159’ TVD 3,333’ UB 36-9AX UB 36-9X UB 38-1 UB 38-4 UB 38-4 UB 38-4 6/7 8/9 B4U/4L/5 B6 5 4 B6 Upper 3 2b B3 2a RA Tag depths: CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor- Driven 72# / L-80 / Weld 12.347” Surf 120’ 7-5/8” Surface 29.7# / L-80 / BTC 6.875” Surf 2,525’ 4-1/2” Production 12.6# / L-80 / DWC/C HT 3.958” Surf 4,466’ Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amount (ft)Date Status Sterling B3 3,446’ 3,450’ 3,138’ 3,142’ 4’9/3/2021 Open Sterling B4U 3,492’ 3,495’ 3,183’ 3,186’ 3’8/31/2021 Isolated (9/1/21) Sterling B4L 3,510’ 3,513’ 3,202’ 3,205’ 3’8/31/2021 Isolated (9/1/21) Sterling B5 3,520’ 3,527’ 3,212’ 3,219’ 7’8/31/2021 Isolated (9/1/21) B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6/25/2020 Isolated (8/30/21) B6 3,705’ 3,710’ 3,396’ 3,401’ 6/28/2019 Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 6/5/2019 Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 4/25/2016 Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 10/2/2015 Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 10/2/2015 Isolated 4,246’ 4,256’ 3,938’ 3,948’ 10/2/2015 Isolated 4,336’ 4,341’ 4,028’ 4,033’ 10/2/2015 Isolated JEWELRY DETAIL No Depth Item 1 1,981’ Baker Swell Packer 2a 3,487’ CIBP with 20’ cement – ToC @ 3467’ MD (9/1/21) 2b 3,638’ CIBP w/ 35’ of cement – TOC @ 3,603’ 08/30/21 3 3,700’ CIBP 06/25/20 4 3,780’ CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 5 3,935’ CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 6 4,238’ Model D Perm Packer, 1.97” ID 7 4,347’ x-nipple, 1.875” ID 8 4,256’ 10K Dual Ceramic Disc, (intact), 1.995 ID 9 4,258’ WLEG, 1.995” ID _____________________________________________________________________________________ Updated by CRR 11-1-2021 PROPOSED SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8: Hole: 157bbls 12ppg lead cement followed by 43bbls 15.4ppg tail cement. No losses. 94bbls cement to surface 4-1/2”6-3/4” hole: 51.6bbls 13.5ppg lead cement followed by 38bbls 15.3ppg tail cement. 15bbl losses during job.ToC ~1,770’ MD from 9/24/15 CBL TD = 4,470’ MD / 4,162‘ TVD 1 RKB: MSL = 18.90’ 4-1/2” 1 3,821’ 4,186’ 13-3/8” 7-5/8” 2,932’ PBTD = 3,467’ MD / 3,159’ TVD 3,333’ UB 36-9AX UB 36-9X UB 38-1 UB 38-4 UB 38-4 UB 38-4 6/7 8/9 B4U/4L/5 B6 5 4 B6 Upper 3 2b B3 2a RA Tag depths: CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor- Driven 72# / L-80 / Weld 12.347” Surf 120’ 7-5/8” Surface 29.7# / L-80 / BTC 6.875” Surf 2,525’ 4-1/2” Production 12.6# / L-80 / DWC/C HT 3.958” Surf 4,466’ Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amount (ft)Date Status Perfs per sundry Sterling B3 3,446’ 3,450’ 3,138’ 3,142’ 4’9/3/2021 To be isolated Sterling B4U 3,492’ 3,495’ 3,183’ 3,186’ 3’8/31/2021 Isolated (9/1/21) Sterling B4L 3,510’ 3,513’ 3,202’ 3,205’ 3’8/31/2021 Isolated (9/1/21) Sterling B5 3,520’ 3,527’ 3,212’ 3,219’ 7’8/31/2021 Isolated (9/1/21) B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6/25/2020 Isolated (8/30/21) B6 3,705’ 3,710’ 3,396’ 3,401’ 6/28/2019 Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 6/5/2019 Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 4/25/2016 Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 10/2/2015 Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 10/2/2015 Isolated 4,246’ 4,256’ 3,938’ 3,948’ 10/2/2015 Isolated 4,336’ 4,341’ 4,028’ 4,033’ 10/2/2015 Isolated JEWELRY DETAIL No Depth Item 1 1,981’ Baker Swell Packer 2a 3,487’ CIBP with 20’ cement – ToC @ 3467’ MD (9/1/21) 2b 3,638’ CIBP w/ 35’ of cement – TOC @ 3,603’ 08/30/21 3 3,700’ CIBP 06/25/20 4 3,780’ CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 5 3,935’ CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 6 4,238’ Model D Perm Packer, 1.97” ID 7 4,347’ x-nipple, 1.875” ID 8 4,256’ 10K Dual Ceramic Disc, (intact), 1.995 ID 9 4,258’ WLEG, 1.995” ID Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/09/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 213-15 (PTD 215-100) Plug/Perf 08/30/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/09/2021 By Abby Bell at 5:06 pm, Nov 09, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 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: 3,487; 3,638'; 3,700'; Total Depth measured 4,470 feet 3,745 & 3,900 feet true vertical 4,162 feet N/A feet Effective Depth measured 3,467 feet 1,981 & 4,238 feet true vertical 3,159 feet 1,807 & 3,930 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)N/A N/A N/A N/A Baker Swell Pkr, 1,981' MD 1,807' TVD Packers and SSSV (type, measured and true vertical depth)Model D Perm Pkr, N/A 4,238' MD 3,930' 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: Contact Name: Contact Email: Authorized Title:Contact Phone: 321-063 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG 433 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 0 175 Ryan Rupert, Operations Engineer ryan.rupert@hilcorp.com 907-777-8503Dan Marlowe, ASC Team Operations Manager, 907-283-1329 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 0 0512 0 162 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 120' 2,525' 0 Structural TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-100 50-133-20652-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028406 Swanson River / Sterling-Upper Beluga Gas Pool Hilcorp Alaska LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Swanson River Unit (SRU) 213-15 measuredPlugs Junk measured N/A Length 120' 2,525' Size Conductor Surface Intermediate 13-3/8" 7-5/8" Production Liner 4,466' Casing 120' 2,265' 4,158'4,466'4-1/2"7,500psi 6,890psi 8,430psi Burst Collapse 4,790psi t Fra O O 6. A PG , R Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Samantha Carlisle at 12:49 pm, Nov 05, 2021 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.05 11:36:17 -08'00' Dan Marlowe (1267) SFD 11/5/2021 RBDMS HEW 11/5/2021 BJM 11/9/21 DSR-11/8/21 Rig Start Date End Date 8/30/21 9/2/21 09/01/2021 - Wednesday CREW ARRIVES/ PERMITS/ JSA. STANDBY FOR INSTRUCTION. RIG UP. RIH W/ GPT TAGGED FLUID @ 670' PRESSURED UP TO 1,250 TAGGED AT 1,724', 2,045, 2,492', 2,850', 3,140', 3190' INCREASED PRESSURE TO 2,000PSI TAGGED @ 3,340', 3,420', 3,498'. MAKE CORRELATION PASS. SEND TO TOWN. MAKE -1' CORRECTION SPOT AND SET 3.71" CIBP @ 3,487'. POOH. RIH W/ 3-1/2" X 25' CMT DUMP BAILER WITH 12.6 GALS OF 16# CMT FOR 20' OF FILL T.O.C. = 3,467'. SECURE WELL. LAYDOWN EQUIPMENT FOR NIGHT. SIGN OUT LEAVE FACILITY. 09/02/2021 - Thursday E-line arrives at location. PJSM, permits, JSA. Rig up E-line. PT 250 low/3,000 high. RIH W/ 2-7/8" x 4' HSC. MAKE CORRELATION PASS, SEND TO TOWN. NO SHIFT REQUIRED. SPOT AND SHOOT 3,446'-3,450'. GOOD INDICATION.POOH. STANDBY FOR WELL TO STABILIZE. THEN PRODUCTION WILL FLOW WELL. RIG DOWN EQUIPMENT. MOVE TO NEXT WELL. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00-00 215-100 08/31/2021 - Tuesday E-line crew arrives at location, permits, JSA. Rig up E-line. RIH W/ 2-7/8" 6SPF CSG GUNS 7' / 3' / 3' WITH SWITCHES. PRESSURE UP TO 1,100PSI WITH GAS. MAKE CORRELATION PASS. SEND TO TOWN. NO DEPTH CORRECTION NEEDED. SPOT AND SHOOT 3,520'-3,527'. POOH. E-LINE STANDBY WHILE PRODUCTION FLOWS WELL. RIH W/ 2-7/8" 6SPF CSG GUNS 3' / 3' PERF. MAKE CORRELATION PASS. SEND TO TOWN, NO DEPTH CORRECTION NEEDED. SPOT AND SHOOT 3,510'-3,513' STANDBY FOR PRESSURES. NO INCREASE PRESSURE WELL BACK UP, SPOT AND SHOOT 3,492'-3,495'. POOH. PRODUCTION FLOWS WELL. E-LINE LAYS DOWN LUBRICATOR FOR THE NIGHT. SIGN OUT LEAVE FACILITY. 08/30/2021 - Monday E-line crew arrives at location. Permits, JSA Jobscope. Rig up E-Line. Rig up hose to jump pressure from GL to tubing. RIH W/ GR-CCL AND 3.50" CIBP SET @ 3,638'. Good break and weight loss. POOH. RIH W/ CCL AND 3.5" X 25' CMT DUMP BAILER FOR 17.5' OF FILL T.O.C. = ~ 3,620.5'. RIH W/ CCL AND 3.5" X 25' CMT DUMP BAILER FOR 17.5' OF FILL T.O.C. = ~ 3,603'. E-LINE LAYS LUBRICATOR DOWN FOR NIGHT. SIGN OUT LEAVE LOCATION. Daily Operations: SHOOT 3,446'-3,450'. SHOOT 3,492'-3,495'. SHOOT 3,510'-3,513' S SHOOT 3,520'-3,527'. SET 3.71" CIBP @ 3,487'. _____________________________________________________________________________________ Updated by CRR 11-1-2021 SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 OPEN HOLE / CEMENT DETAIL 7-5/8"9-7/8: Hole: 157bbls 12ppg lead cement followed by 43bbls 15.4ppg tail cement. No losses. 94bbls cement to surface 4-1/2”6-3/4” hole: 51.6bbls 13.5ppg lead cement followed by 38bbls 15.3ppg tail cement. 15bbl losses during job.ToC ~1,770’ MD from 9/24/15 CBL TD = 4,470’ MD / 4,162‘ TVD 1 RKB: MSL = 18.90’ 4-1/2” 1 3,821’ 4,186’ 13-3/8” 7-5/8” 2,932’ PBTD = 3,467’ MD / 3,159’ TVD 3,333’ UB 36-9AX UB 36-9X UB 38-1 UB 38-4 UB 38-4 UB 38-4 6/7 8/9 B4U/4L/5 B6 5 4 B6 Upper 3 2b B3 2a RA Tag depths: CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor- Driven 72# / L-80 / Weld 12.347” Surf 120’ 7-5/8” Surface 29.7# / L-80 / BTC 6.875” Surf 2,525’ 4-1/2” Production 12.6# / L-80 / DWC/C HT 3.958” Surf 4,466’ Zone Top (MD)Btm (MD) Top (TVD) Btm (TVD)Amount (ft)Date Status Sterling B3 3,446’ 3,450’ 3,138’ 3,142’ 4’9/3/2021 Open Sterling B4U 3,492’ 3,495’ 3,183’ 3,186’ 3’8/31/2021 Isolated (9/1/21) Sterling B4L 3,510’ 3,513’ 3,202’ 3,205’ 3’8/31/2021 Isolated (9/1/21) Sterling B5 3,520’ 3,527’ 3,212’ 3,219’ 7’8/31/2021 Isolated (9/1/21) B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6/25/2020 Isolated (8/30/21) B6 3,705’ 3,710’ 3,396’ 3,401’ 6/28/2019 Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 6/5/2019 Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 4/25/2016 Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 10/2/2015 Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 10/2/2015 Isolated 4,246’ 4,256’ 3,938’ 3,948’ 10/2/2015 Isolated 4,336’ 4,341’ 4,028’ 4,033’ 10/2/2015 Isolated JEWELRY DETAIL No Depth Item 1 1,981’ Baker Swell Packer 2a 3,487’ CIBP with 20’ cement – ToC @ 3467’ MD (9/1/21) 2b 3,638’ CIBP w/ 35’ of cement – TOC @ 3,603’ 08/30/21 3 3,700’ CIBP 06/25/20 4 3,780’ CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 5 3,935’ CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 6 4,238’ Model D Perm Packer, 1.97” ID 7 4,347’ x-nipple, 1.875” ID 8 4,256’ 10K Dual Ceramic Disc, (intact), 1.995 ID 9 4,258’ WLEG, 1.995” ID ()() Sterling B3 3,446’ 3,450’ 3,138’ 3,142’ 4’9/3/2021 Open (MD)(ft) 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 3,638'; 3,700'; Total Depth measured 4,470 feet 3,745 & 3,900 feet true vertical 4,162 feet N/A feet Effective Depth measured 3,603 feet 1,981 & 4,238 feet true vertical 3,295 feet 1,807 & 3,930 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) Baker Swell Pkr, 1,981' MD 1,807' TVD Packers and SSSV (type, measured and true vertical depth)Model D Perm Pkr, N/A 4,238' MD 3,930' TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Todd Sidoti Authorized Title:Operations Manager Contact Email: Contact Phone:777-8443 WINJ WAG 433 Water-Bbl MD 120' 2,525' 0 Oil-Bbl measured true vertical Packer 4-1/2"4,466'4,158' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Sterling-Upper Beluga Gas PoolN/A measured TVD Tubing Pressure 1620 Swanson River Unit (SRU) 213-15 N/A FEDA028406 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-100 50-133-20652-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-063 175 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 512 0 Representative Daily Average Production or Injection Data 120' 2,525' 4,466' Conductor Surface Intermediate Production 7,500psi Casing Structural 13-3/8" 7-5/8" Length 6,890psi Collapse 4,790psi todd.sidoti@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 8,430psi 120' 2,265' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 3:23 pm, Sep 30, 2021 EiEi Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.09.30 13:03:17 -08'00' Taylor Wellman (2143) RBDMS HEW 10/1/2021 BJM 11/4/21 SFD 10/5/2021DSR-10/5/21 Rig Start Date End Date 8/30/21 9/2/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00-00 215-100 08/31/2021 - Tuesday E-line crew arrives at location, permits, JSA. Rig up E-line. RIH W/ 2-7/8" 6SPF CSG GUNS 7' / 3' / 3' WITH SWITCHES. PRESSURE UP TO 1,100PSI WITH GAS. MAKE CORRELATION PASS. SEND TO TOWN. NO DEPTH CORRECTION NEEDED. SPOT AND SHOOT 3,520'-3,527'. POOH. E-LINE STANDBY WHILE PRODUCTION FLOWS WELL. RIH W/ 2-7/8" 6SPF CSG GUNS 3' / 3' PERF. MAKE CORRELATION PASS. SEND TO TOWN, NO DEPTH CORRECTION NEEDED. SPOT AND SHOOT 3,510'-3,513' STANDBY FOR PRESSURES. NO INCREASE PRESSURE WELL BACK UP, SPOT AND SHOOT 3,492'-3,495'. POOH. PRODUCTION FLOWS WELL. E-LINE LAYS DOWN LUBRICATOR FOR THE NIGHT. SIGN OUT LEAVE FACILITY. 08/30/2021 - Monday E-line crew arrives at location. Permits, JSA Jobscope. Rig up E-Line. Rig up hose to jump pressure from GL to tubing. RIH W/ GR-CCL AND 3.50" CIBP SET @ 3,638'. Good break and weight loss. POOH. RIH W/ CCL AND 3.5" X 25' CMT DUMP BAILER FOR 17.5' OF FILL T.O.C. = ~ 3,620.5'. RIH W/ CCL AND 3.5" X 25' CMT DUMP BAILER FOR 17.5' OF FILL T.O.C. = ~ 3,603'. E-LINE LAYS LUBRICATOR DOWN FOR NIGHT. SIGN OUT LEAVE LOCATION. Daily Operations: SPOT AND SHOOT 3,492'-3,495'. RIH W/ CCL AND 3.5" X 25' CMT DUMP BAILER FOR 17.5' OF FILL T.O.C. = ~ 3,603'. SPOT AND SHOOT 3,510'-3,513' SPOT AND SHOOT 3,520'-3,527'. 3.50" CIBP SET @ 3,638' _____________________________________________________________________________________ Updated by DMA 09-16-21 SCHEMATIC Swanson River Field Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor- Driven 72# / L-80 / Weld 12.347”Surf 120’ 7-5/8”Surface 29.7# / L-80 / BTC 6.875”Surf 2,525’ 4-1/2”Production 12.6# / L-80 / DWC/C HT 3.958”Surf 4,466’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)SPF Date Size Status Sterling B4U 3,492’ 3,495’ 3,183’ 3,186’ 6 8/31/2021 2-7/8’Open Sterling B4L 3,510’ 3,513’ 3,202’ 3,205’ 6 8/31/2021 2-7/8’Open Sterling B5 3,520’ 3,527’ 3,212’ 3,219’ 6 8/31/2021 2-7/8’Open B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6 6/25/2020 2-7/8”Isolated B6 3,705’ 3,710’ 3,396’ 3,401’ 5 6/28/2019 2-7/8”Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 2 6/5/2019 2-7/8”Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 6 4/25/2016 2-7/8”Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 6 10/2/2015 2-7/8”Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 6 10/2/2015 2-7/8”Isolated 4,246’ 4,256’ 3,938’ 3,948’ 6 10/2/2015 2-7/8”Isolated 4,336’ 4,341’ 4,028’ 4,033’ 6 10/2/2015 2-7/8”Isolated JEWELRY DETAIL No Depth Item 1 1,981’Baker Swell Packer 2 3,638’CIBP w/ 35’ of cement – TOC @ 3,603’ 08/30/21 3 3,700’CIBP 06/25/20 4 3,780’CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 5 3,935’CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 6 4,238’Model D Perm Packer, 1.97” ID 7 4,347’x-nipple, 1.875” ID 8 4,256’10K Dual Ceramic Disc, (intact), 1.995 ID 9 4,258’WLEG, 1.995” ID (MD)(MD)(TVD)(TVD) Sterling B4U 3,492’ 3,495’ 3,183’ 3,186’ 6 8/31/2021 2-7/8’Open Sterling B4L 3,510’ 3,513’ 3,202’ 3,205’ 6 8/31/2021 2-7/8’Open Sterling B5 3,520’ 3,527’ 3,212’ 3,219’ 6 8/31/2021 2-7/8’Open (MD)(MD)(TVD)(TVD) David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Hilcorp North Slope, LLC Date: 06/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type SRU 11-22 50133206120000 213055 11/3/2020 PERF GAMMA RAY SRU 12-15 50133101380000 183032 10/14/2020 SET PLUG SRU 12-15 50133101380000 183032 10/21/2020 PERF GAMMA RAY SRU 213-15 50133206520000 215100 6/25/2020 PERF GAMMA RAY/GPT SRU 241-16 50133205400000 204088 10/13/2020 PERF GAMMA RAY SRU 241-16 50133205400000 204088 3/30/2021 PERF GAMMA RAY KGSF 1A 50133101600100 220063 11/13/2020 PERF GAMMA RAY Please include current contact information if different from above. 06/28/2021 Received By: 37' (6HW By Abby Bell at 12:21 pm, Jun 28, 2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 4,470'N/A Casing Collapse Structural Conductor Surface 4,790 psi Intermediate Production 7,500 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Todd Sidoti Operations Manager Contact Email: Contact Phone: 777-8443 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized 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: 2/15/2021 N/A 4,466' Perforation Depth MD (ft): See Attached Schematic 4,466' 4,158'4-1/2" 13-3/8" 7-5/8" 120.0' 2,525'6,890 psi 120.0' 2,265' 120.0' 2,525' N/A TVD Burst N/A 8,430 psi MDLength Size CO 716.001 Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 028406 215-100 50-133-20652-00-00 Swanson River Unit (SRU) 213-15 Swanson River / Sterling/Upper Beluga Gas Pool COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): See Attached Schematic todd.sidoti@hilcorp.com 4,162'3,700'3,392'~ 1,181 psi 3,700' / 3,780' / 3,395' Baker Swell Pkr; Model D Perm Pkr; N/A 1,981' MD / 1,807' TVD; 4,238' MD / 3,930' TVD; N/A Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 4:08 pm, Jan 29, 2021 321-063 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.01.29 13:49:59 -09'00' Taylor Wellman (2143) 10-404 Perforate X CO 716 and DSR-2/1/21gls 2/1/21 DLB 02/01/2021 SFD 2/2/2021 r: N2 Comm. 2/2/21 dts 2/2/2021 JLC 2/2/2021 RBDMS HEW 2/3/2021 Well Prognosis Well: SRU 213-15 Date: 1-18-2021 Well Name: SRU 213-15 API Number: 50-133-20652-00-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: February 15th, 2021 Rig: E-Line Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-100 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (O) (985) 867-0665 (M) AFE Number: Max. Expected BHP: ~ 1,520 psi @ 3,388’ TVD (Based on normal pressure gradient) Max. Potential Surface Pressure: ~ 1,181 psi (Based on expected BHP and gas gradient to surface (0.1 psi/ft)) Brief Well Summary SRU 213-15 was drilled and completed in September 2015. In October 2015 the UB-39-6X and bottom of 36-9X sand were perforated, then a packer set with a ceramic disk over the bottom of the 36-9X and 39-6X. In April 2016 the Sterling B8 was perforated. In June 2017 a capillary string was installed down to 3,945’ KB and retrieved one week later. Fill was bailed down to 4,242’ KB and a capillary string was installed down to 3,800’ KB. Two weeks later, in July 2017 the capillary string was retrieved. In March/April of 2019 fill was tagged at 3,946’ KB (“thick, grey mud”). A plug was set at 3,935’ with 22 gal of cement dumped on top to an est. TOC of 3,900’. In June 2019 the Sterling B7 was perforated. Lost tools by cutting wire in master valve. Eventually fished/bailed down to 3,814’ KB and set plug at 3,780’ KB and dumped cement (TOC 3,745’ KB). The Sterling B6, B5 and B4 were then perforated. The purpose of this sundry/work is to perforate the Sterling B5, B4, B3, B2 and B1 sands. Notes Regarding Wellbore Condition x Well is currently producing about 450 MCFD E-Line Procedure 1. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. RIH and perforate the following intervals with 2-7/8” HSD guns: Sand TOP MD BOT MD Total TOP TVD BOT TVD Sterling B1 3259’ 3265’ 6 2951’ 2957’ Sterling B2U 3355’ 3360’ 5 3047’ 3052’ Sterling B2L 3417’ 3421’ 4 3108’ 3112’ Sterling B3 3447’ 3458’ 11 3138’ 3150’ Sterling B4U 3492’ 3495’ 3 3183’ 3186’ Sterling B4L 3510’ 3513’ 3 3202’ 3205’ Sterling B5 3519’ 3526’ 7 3211’ 3218’ a. Final perfs tie-in sheet will be provided in the field for exact perf intervals. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer and Geologist for confirmation. Well Prognosis Well: SRU 213-15 Date: 1-18-2021 c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. d. All perforations in table above are located in the Sterling/Upper Beluga Gas Pool based on Conservation Order 716.001. 3. RDMO E-line. 4. Turn well over to production. Contingent Procedure: If zone produces water and needs to be isolated 1. MIRU N2 unit. a. Ensure that standard nitrogen procedure is reviewed during PJSM. 2. RIH with GPT and determine fluid level. 3. Depress fluid into perforations with N2. 4. Set CIBP above zone. 5. Dump bail 35’ of cement on plug. Attachments 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations pp All perforations in table above are l g cated in the Sterling/Upper Beluga Gas Pool based on Conservation Order 716.001. _____________________________________________________________________________________ Updated by DMA 07-15-20 SCHEMATIC Swanson River Field Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor- Driven 72# / L-80 / Weld 12.347” Surf 120’ 7-5/8” Surface 29.7# / L-80 / BTC 6.875” Surf 2,525’ 4-1/2” Production 12.6# / L-80 / DWC/C HT 3.958” Surf 4,466’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Size Status B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6 6/25/2020 2-7/8” Open B6 3,705’ 3,710’ 3,396’ 3,401’ 5 6/28/2019 2-7/8” Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 2 6/5/2019 2-7/8” Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 6 4/25/2016 2-7/8” Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 6 10/2/2015 2-7/8” Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 6 10/2/2015 2-7/8” Isolated 4,246’ 4,256’ 3,938’ 3,948’ 6 10/2/2015 2-7/8” Isolated 4,336’ 4,341’ 4,028’ 4,033’ 6 10/2/2015 2-7/8” Isolated JEWELRY DETAIL No Depth Item 1 1,981’ Baker Swell Packer 1A 3,700’ CIBP 06/25/20 2 3,780’ CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 3 3,935’ CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 4 4,238’ Model D Perm Packer, 1.97” ID 5 4,347’ x-nipple, 1.875” ID 6 4,256’ 10K Dual Ceramic Disc, (intact), 1.995 ID 7 4,258’ WLEG, 1.995” ID _____________________________________________________________________________________ Updated by TCS 01-19-21 PROPOSED SCHEMATIC Swanson River Field Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor- Driven 72# / L-80 / Weld 12.347” Surf 120’ 7-5/8” Surface 29.7# / L-80 / BTC 6.875” Surf 2,525’ 4-1/2” Production 12.6# / L-80 / DWC/C HT 3.958” Surf 4,466’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Size Status Sterling B1 3259’ 3265’ 2951’ 2957’ 6 TBD 2-7/8’ - Sterling B2U 3555’ 3560’ 3047’ 3052’ 6 TBD 2-7/8’ - Sterling B2L 3417’ 3421’ 3108’ 3112’ 6 TBD 2-7/8’ - Sterling B3 3447’ 3458’ 3138’ 3150’ 6 TBD 2-7/8’ - Sterling B4U 3492’ 3495’ 3183’ 3186’ 6 TBD 2-7/8’ - Sterling B4L 3510’ 3513’ 3202’ 3205’ 6 TBD 2-7/8’ - Sterling B5 3519’ 3526’ 3211’ 3218’ 6 TBD 2-7/8’ - B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6 6/25/2020 2-7/8” Open B6 3,705’ 3,710’ 3,396’ 3,401’ 5 6/28/2019 2-7/8” Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 2 6/5/2019 2-7/8” Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 6 4/25/2016 2-7/8” Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 6 10/2/2015 2-7/8” Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 6 10/2/2015 2-7/8” Isolated 4,246’ 4,256’ 3,938’ 3,948’ 6 10/2/2015 2-7/8” Isolated 4,336’ 4,341’ 4,028’ 4,033’ 6 10/2/2015 2-7/8” Isolated JEWELRY DETAIL No Depth Item 1 1,981’ Baker Swell Packer 1A 3,700’ CIBP 06/25/20 2 3,780’ CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 3 3,935’ CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 4 4,238’ Model D Perm Packer, 1.97” ID 5 4,347’ x-nipple, 1.875” ID 6 4,256’ 10K Dual Ceramic Disc, (intact), 1.995 ID 7 4,258’ WLEG, 1.995” ID 2525ft swell packer STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: 3,700'; Total Depth measured 4,470 feet 3,745 & 3,900 feet true vertical 4,162 feet N/A feet Effective Depth measured 3,700 feet 1,981 & 4,238 feet true vertical 3,392 feet 1,807 & 3,930 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) Baker Swell Pkr, 1,981' MD 1,807' TVD Packers and SSSV (type, measured and true vertical depth)Model D Perm Pkr, N/A 4,238' MD 3,930' 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:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 131 Water-Bbl MD 120' 2,525' 0 Oil-Bbl measured true vertical Packer 4-1/2"4,466'4,158' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Sterling-Upper Beluga Gas PoolN/A measured TVD Tubing Pressure 2200 Swanson River Unit (SRU) 213-15 N/A FEDA028406 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-100 50-133-20652-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-263 890 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 1,314 0 Representative Daily Average Production or Injection Data 120' 2,525' 4,466' Conductor Surface Intermediate Production 7,500psi Casing Structural 13-3/8" 7-5/8" Length 6,890psi Collapse 4,790psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 8,430psi 120' 2,265' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 12:59 pm, Jul 24, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.07.24 11:06:37 -08'00' Taylor Wellman SFD 7/28/2020 RBDMS HEW 7/24/2020 gls 9/2/20 DSR-7/24/2020 Rig Start Date End Date E-Line 6/25/20 6/25/20 06/25/2020 - Thursday PTW, JSA and SIMOPS w/ AKE-Line. Spot equipment and rig up lubricator. PT to 250 psi low and 2,000 psi high. TP - 1,400 psi. RIH w/GPT tool, tie into OHL and tag at 3,720'. Found fluid level 3,458. Ran correlation log and send to town. Call town and decision was made to push back water and set plug. POOH Yellowjacket had to go to town and find Jenneca to get the GEO Plug. WO plug. RIH w GPT, 3.75" GR/Junk basket, tie into OHL and go down right above open perfs at 3,705' and start pushing fluid away with gas. Saw fluid go away with 2,200 psi on tubing. POOH and pick up plug. RIH w/3.71' CIBP and tie into GPT tool. Spot top of plug at 3,700'. Put 2,200 psi back on tubing and set plug. Lost 150 lb line tension. PU 30' and go back and tag plug. POOH. Tubing still holding 2,200 psi. Setting tool look good and pressure holding. RIH w/ 2-7/8" x 5' HC, Razor, 6 spf, 60 deg phase and tie into GPT tool log. Run correlation log and send to town. Bled well to 1200 psi while sending log and waiting on answer. Get ok to perf from 3,688' to 3,693' with 1,220 psi on well. Spotted and fired shot. Gained 30 psi in 15 min (1250 psi). POOH. All shots fired and gun was dry. Rig down lubricator and turn well over to field. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name SRU 213-15 50-133-20652-00 215-100 Get ok to perf from 3,688' to 3,693' with Spot top of plug at 3,700' _____________________________________________________________________________________ Updated by DMA 07-15-20 SCHEMATIC Swanson River Field Well: SRU 213-15 API #: 50-133-20652-00-00 PTD: 215-100 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor- Driven 72# / L-80 / Weld 12.347” Surf 120’ 7-5/8” Surface 29.7# / L-80 / BTC 6.875” Surf 2,525’ 4-1/2” Production 12.6# / L-80 / DWC/C HT 3.958” Surf 4,466’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Size Status B6 (Upper) 3,688’ 3,693’ 3,380’ 3,385’ 6 6/25/2020 2-7/8” Open B6 3,705’ 3,710’ 3,396’ 3,401’ 5 6/28/2019 2-7/8” Isolated UB_36-9X 3,864’ 3,866’ 3,555’ 3,558’ 2 6/5/2019 2-7/8” Isolated UB 36-9AX 3,978’ 3,998’ 3,670’ 3,690’ 6 4/25/2016 2-7/8” Isolated UB 38-1 4,145’ 4,155’ 3,837’ 3,847’ 6 10/2/2015 2-7/8” Isolated UB 38-4 4,218’ 4,223’ 3,910’ 3,915’ 6 10/2/2015 2-7/8” Isolated 4,246’ 4,256’ 3,938’ 3,948’ 6 10/2/2015 2-7/8” Isolated 4,336’ 4,341’ 4,028’ 4,033’ 6 10/2/2015 2-7/8” Isolated JEWELRY DETAIL No Depth Item 1 1,981’ Baker Swell Packer 1A 3,700’ CIBP 06/25/20 2 3,780’ CIBP w/ 35’ cement – TOC @ 3,745’ 06/27/19 3 3,935’ CIBP w/ 35’ cement – TOC @ 3,900 04/12/19 4 4,238’ Model D Perm Packer, 1.97” ID 5 4,347’ x-nipple, 1.875” ID 6 4,256’ 10K Dual Ceramic Disc, (intact), 1.995 ID 7 4,258’ WLEG, 1.995” ID Open 2-7/8”6/25/2020 63,385’3,380’B6 (Upper)3,688’3,693’ By Samantha Carlisle at 8:42 am, Jun 16, 2020 320-263 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.06.15 17:16:17 -08'00' Taylor Wellman *MIT-IA to 1500 psi (30 min) 10-404 DSR-6/16/2020 X DLB 6/16/2020 gls 6/16/20 6/17/2020 dts 6/16/2020 JLC 6/16/2020 RBDMS HEW 6/18/2020 Note: MIT-IA to 1500 psi before perforating 2525' MIT-IA to 1500 psi cement packer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r EL E i V E .M. JUL 16 2013 A<lr�f4h" 1. Operations Abandon Plug Perforations 4 Fracture Stimulate Li Pull Tubing Li perations shutdown LJ Performed: Suspend ❑ Perforate ❑✓ f Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ �rforate New Pool ❑ Repair Well 11 Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ Stratigraphic❑ Service ❑ 215-100 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20652-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: A028406 Swanson River Unit (SRU) 213-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River/ Sterling/Upper Beluga Gas Pool 11. Present Well Condition Summary: Total Depth measured 4,470 feet Plugs measured 3,745 & 3,900 feet true vertical 4,162 feet Junk measured N/A feet Effective Depth measured 3,745 feet Packer measured 1,981 & 4,238 feet true vertical 3,437 feet true vertical 1,807 & 3,930 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 13-3/8" 120' 120' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.6# / L-80 4,258' MD 3,950' TVD Baker Swell Pkr, 1,981' MD 1,807' TVD Packers and SSSV (type, measured and true vertical depth) Model D Perm Pkr, N/A 4,238' MD 3,930' TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 880 Subsequent to operation: 0 1500 0 0 925 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 Gas r WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-067 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkrameKe7hilcem.cem / 1 l Authorized Signature: Date: � 6 J �^1 w i Contact Phone: 777-8420 r. Form 10-404 Revised 4/2017 RBDMS XWJIUL 1 81019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 215-100 3/28/19 1 6/28/19 Daily Operations: 03/28/2019 - Thursday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. Field ran high pressure hose to pressure up well while we tubing punched SRU 21A-34. RIH w/GPT tool with 1,900 psi on tubing. Found fluid level at 750'. Pressured well up to 2,250 psi for 1 hour and checked again and FL was at 752'. Called town and discussed. Moved high pressure hose to SRU 242-16 and will leave it on all night to try and push fluid away. Will check in the morning. Rig down lubricator and turn well over to field. We will probably have to get N2 out to push fluid away. After we check SRU 242-16 fluid level we will know how much N2 to order. 03/29/2019 - Friday ARRIVE S.R. MEET W/ BILLY TGSM JSA PERMIT. RIG UP SLICKLINE P/T 2,500PSI GOOD TP - 2,100 PSI. RIH W/ 2.5" DD BAILER TO 3,946'KB TAG W/ TOOL. POOH. FULL OF THICK GRAY MUD. RIH W/ 3.65" G -RING TO 3,946'KB. TAG W/ TOOL. POOH. LOOK LIKE FLUID LEVEL WAS 775' KB. RIG DOWN EQUIPMENT AND MOVE TO SRU 242-16. 04/12/2019 - Friday PTW and JSA. Spot and rig up lubricator. PT to 250 psi low ands 3,000 psi high. TP - 1,900 psi, RIH with 3.50" OD plug and tie into OHL. Tag at 3,936'. Set plug at 3,935' with 1,900 psi on tubing, lost 150 Ib line tension when plug set. Pick up 30' and go back and tag plug. POOH. Looks good. Bled tubing down to 1,000 psi. Make 4 runs of 3" x3 O' cement dump bailer (22 gals total 16.2 ppg cement) and dumped on top of plug at 3,935'. Cement in place at 12:15 am. Est TOC at 3,900'. Rig down equipment, turn well back to field and WOC. 04/12/2019 - Friday PTW and JSA. Spot and rig up lubricator. PT to 250 psi low ands 3,000 psi high. TP - 1,900 psi, RIH with 3.50" OD plug and tie into OHL. Tag at 3,936'. Set plug at 3,935' with 1,900 psi on tubing, lost 150 Ib line tension when plug set. Pick up 30' and go back and tag plug. POOH. Looks good. Bled tubing down to 1,000 psi. Make 4 runs of 3" x3 0' cement dump bailer (22 gals total 16.2 ppg cement) and dumped on top of plug at 3,935'. Cement in place at 12:15 am. Est TOC at 3,900'. Rig down equipment, turn well back to field and WOC. 04/22/2019 - Monday Sign in. Mobe to location. PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 2,500 psi high. TP - 1,100 psi. RIH w/GPT w3.30" GR and tie into HLB OHL. Tag at 3,877' and found fluid level at 3,782'. Ran log and send to town. AKE-Line is getting different lubricator and 3" bailer to run down and bail the fluid below the perfs in the morning and perforate tomorrow afternoon. Rig lubricator off well and turn well over to field. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 04/23/2019-Tuesday Sign in. Mobe to location. PTW and JSA. Rig up lubricator. PT to 250 psi low and 2,500 high. TP - 1,100 psi. RIH w/ 3" x 30' bailer and tie into fluid level log (Yesterdays) and go down to 3,800' and let bailer fill up. POOH and dump water out. Did this 30' bailer for 5 runs and then made 4 runs with 3" x 20' bailer to 3,879' (Tag depth). Bailed out approx. 60 gals which should have put us below tag depth. Decided to run GPT and see were fluid level was because we were still getting full bailers out. RIH w GPT and tie into fluid level log and tagged at 3,879'. Found fluid level at 3,767' with 910 psi on well. Fluid level was 3,782' yesterday. Call Town and discussed. Was told to rig off well and will decide what to do next. Leave the pressure on the well and will see if pressure or fluid level changes. POOH and bled lubricator off. TP 880 psi. Rig down lubricator and turn well back over to field. 06/07/2019 - Friday Sign in. Mobe to location. PTW and JSA. Field orientation for 1 service hand. Attempt to PT and had O-ring failure. Tri=plex connection started leaking. Fixed both problems. PT to 250 psi low and 2,500 psi high. 850 psi on well. RIH w/GPT tool and tied into plug log. Tool set down at 3,880'. Found fluid level at 3,764'. Send log to town and POOH. Found a 0-ring cut after we started to stab back on to run perf gun. Put new 0-ring on and PT to 250 psi low and 3,000 psi high. Put crystal gauges on well. RIH w/ 2-7/8" x 2' HC Razor, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and send to town. Get ok to pert from 3,864' to 3,866' with 812 psi on well. Spot and fire gun with 812 psi on well. After 5 min - 1,150 psi, 10 min - 1,209 psi alnd 15 min -1,208.3 psi. POOH. Fired gun at 1715 hrs. All shots fired and gun was wet. Rig down lubricator and turn well over to field. Took crystal gauges off and turned in. 06/10/2019 - Monday Arrive @ Swanson River, talk w/ company rep. Sign permits. Rig up on well (.160). Bleed down well. Approx 100 psi on well. RIH w/ 3.8 G-ring to 3,860' KB, POOH. RIH w/ 4-1/2" Swab Mandrel w/ 2 V-Cups. RIH to 2,625' KB, Wire breaks at 700lbs on surface. Tools are in Lubricator. Possibly dropped small amount of wire down hole while shutting swab. Rig back up. Cut 100' of wire. Well is flowing small amount on its own. FL - 2,625' KB. Find 2, 1' pieces of wire on top of master valve. Has been cut by master, wire below master dropped down hole. Talk w/ sup and decide to lay down for the night. End ticket. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 06/12/2019- Wednesday Arrive @ Swanson River, talk w/ company rep, discuss job scope. Sign permits. Rig up .160 on well. RIH w/ 3.31" G -ring to 3,430' KB, do not set down. POOH. RIH w/ 3.7" wire grab to 3,411' KB, w/t, cant pass, POOH, OOH w/ wire marks on side of grab. RIH w/ 4-1/2". Braided line brush to 3,440' KB don't set down. Picking up extra 50lbs, POOH slowly. OOH w/ brush. RIH w/ 3.6" Swedge to 3,537' set down. POOH. Hang up in TH. Pulling out of hole. RIH w/ 4-1/2" BLB to 3,539' KB, w/t 3,559' KB, making hole but .160 sheave is coming apart. POOH and fix sheav RIH w/ 3.7" Wire Grab to 3,539' KB. w/t 3,543' KB, can get friction bite, POOH, still getting hung up at 3,539'KB. OOH w/ grab, wire marks on side. RIH w/ 3" DD Bailer to 3,539' KB, fall through to 3,551' KB, w/t 3,559' KB, cant pass, POOH. OOH w/ empty bailer. RIH w/ 2.7" 3 prong wire grab baited with XO, 1- 3/4" Rope socket. On 2-1/2" JUS. RIH to 3,559' KB, cant latch w/t 3,562' KB, getting friction bites. POOH. OOH no wire. Wire marks on side on grab body. RIH w/ 4- 1/2" Postitive Key Shifting tool ran facing down to 3,538' KB, w/t, POOH. OOH RIH w/ Baited 3.7" Wire, Grab on 2-1/2" JUC to 3,555' KB, get small bite, pull up 20' set back down at 3,546' KB, w/t, pick up, pulling 90lbs heavier, POOH slowly. OOH, wire is hanging below Master, Shut W/L valves, no wire in WL valves. RIH w/ same, attempt to fish wire out of tree w/ master holding wire up. Cant latch. RIH w/ 3.7" Magnet, set down, on master, open master valve, RIH 10' below TH. POOH, no wire, RIH to 200' KB, POOH, RIH to 3,538' KB, POOH slow. OOH w/ tools, rig down. Depart Swanson River FL - 1,600'. 06/13/2019 - Thursday Arrive @ Swanson River, talk w/ company rep. sign permits, dicussjob scope. Rig up on well. Cut 50' of wire, re -head. PT- 2,500 psi- GOOD. RIH w/ 2.7 Wire -Grab baited on 2-1/2" JUC. RIH too 3,547' KB, w/t, getting friction bites, can latch, POOH. RIH w/ 4-1/2" Positive Key shifting tool facing down to 3,537' KB, w/t, POOH. RIH w/ 2.7" Wire -Grab baited on 2-1/2" JUC. RIH to 3,554' KB, w/t 3,568' KB, Getting friction bites. Dragging up to 3,555' KB. POOH. RIH w/ 3.7 Wire -Grab baited on 2-1/2" JUC. RIH to 3,563' KB, w/t 3,566' KB, POOH. OOH w/ grab. RIH w/ 4-1/2" Shifting tool facing down to 3,536' KB. w/t 3,559' KB, pull up 30 ft, drag heavy untill 3,533' KB, set back down at 3,538' KB, Witt 3,561' KB, pull out dragging, will set down at 3,538 everytime. POOH. OOH, check tool string, add 5' stem. RIH w/ 3.7 Wire -Grab baited, to 18' KB, set down, cant pass, can hear wire in tree. POOH. OOH w/ aprox. 3' of .160 wire. Wire apears to be cut on both ends by master valve. RIH w/ same to 3567' KB, w/t, pick up extra 25 lbs, POOH slow. OOH no wire. RIH w/ 3.8 LIB to 3566' KB, w/t, POOH. OOH clean LIB. No impressions. RIH w/ 3" DD Bailer to 3566' KB w/t 3575' KB, POOH full sand. Talk w/ compan rep. find possible pressure under sand bridge (1200 lbs). RIH w/ 2 1/4 DD Bailer to 3576' KB, w/t 3581' KB. POOH. OOH full sand. RIH w/ same to 3577' KB, w/t 3581' KB, POOH. Full of sand. OOH w/ tools. Rig down. TP - 90 psi. Depart Swanson River. End ticket. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 06/14/2019 - Friday Arrive @ Swanson River, talk w/ company rep, sign permits. Discuss Job scope. Rig up on well. Well has built up to 120psi from 80 psi overnight. PT- 2,500 psi- GOOD. RIH w/ 3" X S' DD Bailer to 3,556' KB, w/t 3,562' KB, POOH, OOH 3/4 full sand. Fluid level - 1,580' TP - 120 psi. RIH w/ same to 3,560'w/t 3,567' KB, w/t POOH full sand. RIH w/ same to 3,567' KB, w/t 3,571' KB, POOH. OOH full sand. RIH w/ same to 3,572' KB, w/t 3,576' KB, POOH. OOH full sand. RIH w/ same to 3,577' KB, w/t 3,579' KB, POOH. OOH full sand. RIH w/ same to 3,580' KB, w/t 3,582' KB, POOH. OOH full sand. RIH w/ 2.25" X 4' DD Bailer to 3,581 w/t 3,583' KB, POOH. OOH full sand. RIH w/ 3" X 5' DD bailer to 3,581' KB, w/t 3,583' KB, POOH. OOH empty. Apears flapper was stuck open. RIH w/ same w/ tyler bottom to 3,584' KB, w/t 3,585' KB, POOH. OOH full sand. RIH w/ same to 3,584' KB, w/t 3,586' KB, POOH. OOH full sand. RIH w/ same to 3,585' KB, w/t 3,586' KB, POOH. OOH full sand. RIH w/ same to 3,586' KB, w/t 3,588' KB, POOH. OOH full sand. RIH w/ same to 3,586' KB, w/t 8,589' KB, POOH. OOH full sand. RIH w/ same to 3,590' KB, w/t 3,592' KB, POOH. OOH full sand. RIH w/ same to 3,591' KB, w/t 3,593' KB, POOH. OOH full sand. RIH w/ same to 3,592' KB, w/t 3,594' KB, POOH. OOH full sand. OOH w/ tools. Lay down, cut wire/ re -head. TP - 90 psi. Depart Swanson. 06/15/2019 -Saturday Arrive @ Swanson River, talk w/ company rep. sign permits, TGSM. Rig up on well. Stem on wing valve has been leaking overnight. Have production grease valve. PT 2,500 psi- GOOD. RIH w/ 3" X 11' DD bailer to 3,574' KB, w/t 3,586 KB, POOH full sand TP 110 psi. RIH w/ same to 3,586' KB w/t 3,596' KB, POOH. OOH 1/2 full sand. RIH w/ same to 3,597' KB w/t 3,599' KB, POOH. OOH full sand. RIH w/ same to 3,598' KB, w/t 3,601' KB, POOH. OOH full sand. Break off bailer, check tool string. RIH w/ same to 3,600' KB, w/t 3,603' KB, POOH. OOH full sand. RIH w/ same to 3,605' KB, w/t 3,608' KB, POOH. OOH full sand. RIH w/ same to 3,607' KB, w/t 3,611' KB, POOH. OOH full sand. RIH w/ same to 3,608' KB, w/t 3,612' KB. POOH. OOH full sand. RIH w/ same to 3,612' KB, w/t 3,617' KB, lose hole up too 3,600' KB. Possibly counter problem, possibly fill coming in. POOH. OOH check tool string and wire, clean counter head. Pressure is @ 140 psi. RIH w/ same to 3,300' KB, set down, POOH.Tubing pressure has come up to 180 psi.00H Bailer full (did not bail) TP climbed to 225 psi Talk w/ B. Applewhite. Decide to put 1,200 psi on well and continue bailing. Begin pressuring up on well. RIH w/ same to (fluid is at 1,400' KB) 3,427' KB, w/t 3,437' KB. POOH. RIH w/ same to (fluid is at 1,400' KB) 3,427' KB, w/t 3,437' KB. POOH, OOH w/ tools, rig down. Depart Swanson River. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 06/16/2019-Sunday Arrive @ Swanson River, talk w/ company rep. Discuss Job scope, sign permits. TGSM. Rig up on well. Check tool string. Pressure up lubricator to 1200 psi before every run. RIH w/ 3" X 11' DD Bailer to 3,637' KB, w/t 3,639' KB, have to jar 11X to come free. POOH. OOH 1/2 full. RIH w/ same to 3,638' KB, w/t, POOH. OOH w/ very small amount of clay. Switch to flapper bottom, RIH w/ same to 3,640' KB, w/t, don't make hole, work lightly, still have to jar free. POOH. OOH w/ small amount of clay. RIH w/ 3" Pump Bailer to 3,639'KB, POOH. OOH w/ empty bailer. RIH w/ 3" X 5' DD Bailer w/ tyler bottom to 3638' KB, w/t, have to jar out 2-3X even when working lightly. POOH, OOH empty. Cut Flapper bottom to have 45 degree angled bottom. RIH w/ same w/ angled flapper bottom to 3,639' KB, w/t POOH. OOH empty. RIH w/ 3.80 g-ring to 30'KB w/t 46' KB, still making hole, POOH. RIH w/ 3" DD Bailer to 60' KB, do not set down. POOH. RIH w/ 3.68 G-ring to 48' KB, w/t still making hole, POOH. Pump methanol down well. (approx. 20 gals). RIH w/ same to 49' KB, tap once, fall through to 1,560' KB (fluid level) set down, work through, fall to 3,638' KB, POOH. RIH w/ 3.8 G-ring to 3,639' KB, POOH. Rig down. Leave 1,200 psi on well. Depart Swanson River. 06/18/2019-Tuesday RIG UP W/L - PT LUB 2,500 PSI - GOOD. RIH W/ 3" X 5' DD BAILER TO 3,639'KB WT - GAIN NO HOLE - POOH - OOH W/ 1/3 FULL HARD CLAY. RIH W/ 1.75" X 5' DD BAILER TO 3,639'KB WT TO 3,641'KB - POOH - OOH W/ 2 CUPS HARD CLAY RIH W/ SAME W/ CHISELE BTM TO 3,640'KB WT TO 3,641'KB POOH - OOH W/ EMPTY BAILER. RIH W/ 3" X VDD BAILER TO 3,639'KB WT TO 3,641'KB - POOH - OOH W/ 1/3 FULL HARD CLAY. BLEED WELL DOWN TO 600 PSI. RIH W/ 3" X 5' DD BAILER TO 1520'KB TAG FLUID - CONT IN HOLE TO 3,640'KB WT TO 3,641'KB - POOH. OOH W/ 1/4 FULL HARD CLAY - BLEED WELL DOWN TO 400 PSI RIH W/ KJ W/ 1.5" X 3' STEM W/ PRONG TO 3,641'KB WT TO 3,642'KB POOH. RIH W/ 3" X 5' PUMP BAILER TO 3,640'KB WT TO 3,641'KB - POOH - OOH W/ EMPTY BAILER. RIH W/ SAME W/ FLAPPER BTM TO 3,640'KB WT TO 3,645'KB - FALL TO 3,733'KB WT TO 3,736'KB. POOH - OOH W/ FULL SAND. RIH W/ 3.80" GAUGE RING TO 3,673'KB WT TO 3,686'KB POOH RIH W/ 3" X 5' DD BAILER TO 3,665'KB WT TO 3,682'KB POOH - OOH W/ FULL SAND. RIH W/ SAME TO 3,672'KB WT TO 3,682'KB POOH - OOH W/ FULL SAND. RIH W/ SAME TO 3,677'KB WT TO 3,683'KB - OOH W/FULL SAND. RIG DOWN FOR THE NIGHT. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 06/19/2019- Wednesday ON LOCATION-TGSM-JSA-PERMIT. RIG UP W/L-PT LUB 2,500PSI- GOOD. RIH W/ 3" X 13' DD BAILER TO 3,669'KB -WT TOO- 3,673'KB POOH -OOH W/ 1/2 BAILER SAND. RIH W/ SAME TO- 3,672' KB - WT TOO- 3,677' KB POOH - OOH W/ 1/2 FULL SAND. RIH W/ 3" X 5' PUMP BAILER TO 3,674'KB WT TO- 3,678' KB POOH - OOH W/ FULL BAILER SAND RIH W/ 3" X 10' PUMP BAILER TO 3,678'KB WT TO- 3,688'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO - 3,688' KB WT TO - 3,693'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,693'KB WT TO 3,703'KB POOH - OOH W/ FULL BAILER SAND - ROD DAMAGED ON PUMP. RIH W 3" X 13' DD BAILER TO 3,700'KB WT TO 3,705'KB - POOH - OOH W/ FULL BAILER SAND. RIH W/SAME TO 3,705'KB WTTO 3,708'KB - POOH - OOH W/ FULL BAILER SAND RIH W/ SAME TO 3,709'KB WT TO 3,717'KB - POOH - OOH W/ FULL SAND. RIH W/ SAME TO 3,714'KB WT TO 3,715'KB POOH - OOH W/ FULL SAND. RIH W/ SAME TO 3,710'KB WT TO 3,714'KB POOH- OOH W/ FULL SAND. RIH W/ SAME TO 3,712'KB WT TO 3,715'KB POOH - OOH W/ FULL SAND. RIH W/ SAME TO 3,114'KB WT TO 3,717'KB - POOH - OOH W/FULL SAND RIG DOWN LUBRICATOR. CUT WIRE AND RE -HEAD LINE. FL - 1,540' and TP - 350 psi. 06/20/2019 - Thursday ON LOCATION - TGSM - JSA - PERMIT. RIG UP W/L - PT LUB TO 2,500 PSI - GOOD TP- 280 PSI. RIH W/ 3" X 13' DD BAILER TO 3,710'KB WT TO 3,712'KB POOH - OOH W/ EMPTY - BROKE FLAPPER. RIH W/ SAME TO 3,711'KB WT TO 3,713'KB POOH - OOH W/ 1/2 FULL BAILER OF SAND RIH W/ 3" X 8' PUMP BAILER TO 3,712'KB WTTO 3,715'KB POOH - OOH W/ 3/4 FULL SAND. RIH W/ SAME TO 3,713'KB WT TO 3,717'KB POOH - OOH W/ 3/4 FULL SAND. RIH W/ 3" X 13' DD BAILER TO 3,714'KB WT TO 3,718'KB POOH - OOH W/ 1/2 FULL SAND. RIH W/ SAME TO 3,715'KB WT TO 3,720 -KB POOH - OOH W/ EMPTY BAILER - BROKE FLAPPER. METAL MARK ON BAILER BOTTOM. IT LOOKS LIKE MAYBE WE HAVE A PIECE OF WIRE IN THE WELL STILL. RIH W/ SAME TO 3,717'KB WT TO 3,721'KB POOH - OOH W/ EMPTY BAILER - BROKEN FLAPPER. POSSIBLY HEAVY DEBRIS BREAKING FLAPPERS - MARKS ON BAILER BTM. RIH W/ 3" X 12' PUMP BAILER TO 3,720'KB WT TO 3,725'KB - POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,723'KB WT TO 3,726'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,728'KB WT TO 3,732'KB POOH - OOH W/ FULL BAILER SAND RIH W/ SAME TO 3,731'KB WT TO 3,740'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,738'KB WT TO 3,741'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,741'KB WT TO TO 3,747' KB POOH. OOH W/FULL BAILER SAND. RIG DOWN LUBRICATOR. GET READY TO MOVE OVER TO 242-16 FOR SURVEY TOMORROW. TP - 240 PSI. DEPART SWANSON. 06/21/2019 - Friday ON LOCATION - TGSM - JSA - PERMIT. RIG UP W/L - PT LUB 2,500 PSI - GOOD TP - 280 psi. RIH W/ 3" X 13' PUMP BAILER TO 3,740'KB WT TO 3,742'KB - POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,742'KB WT TO 3,748'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,746'KB WT TO 3,750'KB POOH - OOH W/ FULL BAILER SAND RIH W/ SAME TO 3,750'KB WT TO 3,755'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,754 -KB WTTO 3,757'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,757'KB WT TO 3,762'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,762'KB WT TO 3,768'KB POOH - OOH W/ FULL BAILER SAND. RIG DOWN W/L MOB TO SRU 242-16 TO RUN SURVEY TP - 275 psi FL - 1,580'. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 06/22/2019 -Saturday MOVE OVER FROM 242-16 - RIG UP W/L - PT LUB - GOOD. RIH W/ 3" X 13' PUMP BAILER TO 3,765'KB WT TO 3,770'KB POOH - OOH W/ 1/2 FULL SAND FL- 1,600'. PRESSURE CLIMBED 30 PSI TO 340 - FLUID LEVEL REMAINS AT 1,600'. RIH W/ SAME TO 3,770'KB WT TO 3,776'KB POOH - OOH W/. RIH W/ SAME TO 3,775-KB WT TO 3,781-KB POOH - OOH W/ FULL BAILER SAND RIH W/ SAME TO 3,780'KB WT TO 3,786'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,783'KB WT TO 3,789'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,790'KB WT TO 3,795'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,796'KB WT TO 3,802'KB POOH - OOH W/ FULL BAILER SAND RIH W/ 3.80" GAUGE RING TO 3,796'KB WT TO 3,797'KB POOH. RIH W/ 3" X 13' PUMP BAILER TO 37,97'KB WT TO 3,804'KB POOH - OOH W/ FULL BAILER SAND 260 psi FL - 1,600'. RIG DOWN W/L - SECURE WELL. MOB TO OFFICE TO CLOSE OUT PERMIT. DEPART FIELD FOR PWL SHOP. 06/23/2019-Sunday ON LOCATION - TGSM - JSA - PERMIT. RIG UP W/L - PT LUB 2,500 PSI - GOOD TP - 340 psi. RIH W/ 3" X 13' PUMP BAILER TO 3,802'KB WT TO 3,805'KB POOH - OOH W/ EMPTY BAILER - BROKE FLAPPER Fluid Level 1,620' RIH W/ SAME TO 3,806'KB WT TO 3,811'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,807'KB WT TO 3,811'KB POOH - OOH W/ FULL BAILER SAND. RIH W/ SAME TO 3,812'KB WT TO 3,817'KB POOH - OOH W/ FULL BAILLER SAND. RIH W/ 3.8" GAUGE RING TO 3,814'KB TAG FILL - POOH RIG DOWN W/L - SECURE WELL - PRODUCTION TO PRESSURE UP W/ GAS BETWEEN 1,900 PSI TO 2200 PSI TIL TOMORROW MORNING WHEN AKE-LINE SHOWS UP TO SET PLUG. RETURN EQUIPMENT TO BULL RAIL. CLOSE OUT PERMITS. DEPART FIELD. 06/24/2019 - Monday PTW and JSA. Spot equipment. Had 2 AKE-Line guys for orientation. Rig up lubricator. PT lubricator to 250 psi low and 2,500 psi high. TP - 2,550 psi. RIH w/GPT tool and tie into OHL. Tagged at 3,780' and found fluid level at 1,632'. Ran log and send to town. POOH Bleed well down to 1,900 psi. RIH w/ 3-1/2" OD CIBP and tie into GPT log. Spotted and set plug at 3,780'. Lost 176 lbs on line tension when plug was set. Picked up 30' and went back down and tagged Plug. POOH and setting tool look like a good set. TP was 1,900 psi when plug was set. MU 3"x30' dump bailer and mix cement. Bleed well down to 850 psi. RIH with 3"x30' cement dump bailer filled with 17 ppg NEO cement and dump on top of plug at 3,780'. POOH. RIH w/2d run of the same and dump bail cement on top of 1st cement run at 3,762.5' (22 gal total). Cement in place at 1600 hrs. Est TOC at 3,745'. Showed good dumps on both runs. Rig down lubricator. Closed both masters and swab valves. Put red flags on valve handles. Will wait 24 hrs to let cement set up. TP was 850 when shut in. I have the 2 cement sample bottles with me. 06/27/2019 - Thursday ON LOCATION - TGSM - JSA - PERMIT. RIG UP .160 WIRELINE - PT LUB 2,500 PSI - GOOD TP - 800 psi. BLEED WELL DOWN TO 0 PSI. RIH W/ 3" X 4' DO BAILER TO 3,745'KB TAG CEMENT - POOH RIH W/ 4-1/2" SWAB MANDREL W/ 2 SWAB CUPS - TO 1,600'KB - BEGIN SWABBING WELL DOWN TO 3,740'KB. OOH W/ SWAB CUPS - RIG DOWN W/L. MOB TO BULL RAIL - FUEL EQUIPMENT - SPOT AT BULL RAIL. DEPART FIELD FOR PWL SHOP NOTE Plan is to perforate tomorrow. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 1 215-100 3/28/19 1 6/28/19 Daily Operations: 06/28/2019 - Friday Sign in. Mobe to location. PTW and JSA. Spot and rig up lubricator. Attempt to pressure test and had o -ring failure. Replaced o -ring. PT to 250 psi low and 2,500 psi high. TP - 1,223 psi. Put crystal gauges on well. RIH w/GPT tool and tag at 3,744' and found fluid level at 3,716'. Run log and send to town. POOH RIH w/ 2-7/8" x 5' Razar HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Get ok to pert from 3,705' to 3,710'. Spotted and fired gun with 1,223 psi on well. After 5 min - 1,219.3 psi, 10 min - 1,213 psi and 15 min - 1,211 psi. Out of hole - 1,207 psi. All shots fired and gun was wet. We lost 3 bow springs off of shock centralizer in well. When we fired gun it shook everything pretty good. Rig down lubricator and turn well over to field. K Nileora Alaska, LLC 133X' '191=10 R4 Tag dmfs: 2932 E 3,333 Type Wt/Grade/Conn TOC3,745' Top Btm 6/27/19 Conductor- Driven B6 12.347" e 2 3,821' - 1 29.7#/L-80/BTC 6.875" Surf UB 36 9X TOC 3,9m Production . 4/W19 Surf 3 6/5/2019 2-7/8" UB 36W 4,186UB 381 UB 38-4 45 B!7 UB 38-0 UB 38-4 TD -4,470' MD/4,162'76/ PBID=4,383' M)/4,075' TVD SCHEMATIC CASING DETAIL Swanson River Field Well: SRU 213-15 API #: 50-133-20652-00 PTD: 215-100 Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor- Driven 72#/L-80/Weld 12.347" Surf 120' 7-5/8" Surface 1 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 1 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 3,784 CIBP w/ 35' cement -TOC @ 3,745' 06/27/19 3 3,935' C1 BP w/35'cement - TOC @3,90004/12/19 4 4,238' Model D Perm Packer, 1.97" ID 5 4,341 x -nipple, 1.875" ID 6 4,256' 10K Dual Ceramic Disc, (intact), 1.9951D 7 4,258' WLEG, 1.995- ID PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Size Status B6 3,705' 3,710' 3,396' 3,401' 5 6/28/2019 2-7/8" Open UB}6-9X 3,864' 3,866' 3,555' 3,558' 2 6/5/2019 2-7/8" lope- UB36-9AX 3,978' 3,998' 3,670' 3,690' 6 4/25/2016 2-7/8" Opea-- UB 38-1 4,145' 4,155' 3,837- 3,847- 6 10/2/2015 2-7/8" Open - 4,218' 4,223' 3,910' 3,915' 6 10/2/2015 2.7/8" Open UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10/2/2015 2-7/8" Isolated 4,336' 4,341' 4,028' 4,033' 6 10/2/2015 2.7/8" Isolated Updated by DMA 07-11-19 THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 213-15 Permit to Drill Number: 215-100 Sundry Number: 319-067 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. a 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, le i� Daniel T. Seamount, Jr. Commissioner y� DATED this Iq dray of February, 2019. RBDMS�' r` tB 14 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AA(' 2.5 280 P-1 '4Y.rym''Ac,, .Y.'/J is V ED FQ t 1 20119 1. Type of Request: Abandon ❑ Plug Perforations ❑� , Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑� • Other Stimulate p Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑� • Stratigraphic ❑ Service ❑ 215-100 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20652-00:—t�c� 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 71 't3 , : I Z.;y, Will planned perforations require a spacing exception? Yes LiNo ❑� 2' Swanson River Unit 213-15 9. Property Designation (Lease Number): 10. Field/Pool(s): A028406 Swanson River/ Sterling/Upper Beluga Gas Pool 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): 4,470' . 4,162' 4,383' 4,075' 1,262 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 13-3/8" 120' 102' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6f1 / L-80 4,258' Packers and SSSV Type: Packers and SSSV MD ft) and TVD (ft): Baker Swell Pkr; Model D Perm Pkr; N/A 1,981' MD/1,807' TVD; 4,238' MD/3,930' TVD; /N/A 12. Attachments: Proposal Summary Wellbore schematic L4J 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development [D Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 25, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑Q WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasseGDhilcem.cem Contact Phone: 777-8354 % PL� L Authorized Signature: Date: -I\''1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 19 _ OUT Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes El/ No F Subsequent Form Required: % 0 _ LfoG r APPROVED / I Approved by: COMMISSIONER THEHECOMMISSION ISSISI ON Date: / V' Pon70-403 Revised 4/2017/ &P� ZAprove applicatO'lip ] N- A [he Rv/nna' lO\.FED 14 2 Submit Form and .�� hnn is 'uy,Duplicate H Hilmrp Alaska, LU Well Prognosis Well: SRU 213-15 Date: 2/4/2019 Well Name: SRU 213-15 API Number: 50-133-20652-00 Current Status: SI Gas Well Leg: N/A Estimated Start Date: February 25th, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: ±2,854' Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-100 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: 6 Sterling B2 Maximum Expected BHP: Max. Potential Surface Pressure Brief Well Summary 1,643 psi @ 3,822' TVD (based on 0.43 psi/ft gradient) 1,262 psi (Based on 0.1 psi/ft gas gradient to surface) SRU 213-15 was drilled as a Grass roots monobore completion in 2015 to target gas sands in the Sterling/Upper Beluga formations. In October 2015, 2 zones were perforated in 4 different sands. The well began to make water, so a packer with a ceramic disk were installed. The well declined until it no longer flowed to surface in June 2017. The purpose of this work/sundry is to add perforations in the Sterling /Upper Beluga formation. Notes Regarding Wellbore Condition • Plan to tag/drift with slickline before running E -line. • Prior to a setting a plug (contingency), water will be pushed away with gas or swabbed down. E -line Procedure: 1. MIRU E -line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU 2-7/8" 6 spf wireline guns. 3. RIH and perforate the following intervals and test zones individually: Zone Sands (Mp) Btm (MD) FT SPF Sterling A7 ±2,789' ±2,792' 3 6 Sterling A7 ±2,840' ±2,854' 14' 6 Sterling A8 ±2,957' ±2,962' S' 6 Sterling B2 ±3,145' ±3,151' 6' 6 Sterling B2 ±3,174' ±3,187' 13' 6 Sterling B3 ±3,355' ±3,380' 25' 6 Sterling B4 ±3,445' ±3,460' 15' 6 Sterling B5 ±3,520' ±3,525' S' 6 Sterling B6 ±3,705' ±3,710' S' 6 Beluga UB 36-9X ±3,864' ±3,869' S' 6 Beluga UB 36-9X ±3,925' ±3,930' S' 6 Beluga UB 36-9AX ±4,037' ±4,040' 3' 6 H Ialmm Naeka, LU Beluga UB 36-9AX ±4,069' ±4,074' S' 6 Beluga UB 36-9AX ±4,109' ±4,114' S' 6 Beluga UB 36-9AX ±4,126' ±4,131' S' 6 Well Prognosis Well: SRU 213-15 Date: 2/4/2019 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 Correlation Log. d. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. e. Install Crystal gauges. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Sterling/Upper Beluga Pool based on Conservation Order No. 716. 4. RD E -line. 5. Turn well over to production. E -line Procedure (Contineencvl: 6. If any zone produces sand and/or water or needs isolated 7. MIRU E -line, PT lubricator to 2,500 psi Hi 250 Low. a. SITP will be +/- 1,200 psi (remaining gas). 8. RIH and set 4-1/2" CIBP within 50' above zone. 9. RU dump bailer. RIH with cement and dump bail 35' of cement on CIBP. POOH. 10. Continue with steps 2-5. Or 11. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic Ililwra Alueka. LLC RKB: MSL =18.90 u RA Tag depths: ± 2937 Type Wt/Grade/Conn t r I Btm 13-3/8" Conductor- Driven 72#/L-80/Weld 12.347" Surf 120 7-5/8" Surface 29.7#/L-80/BTC 6.875" r: 2,525' 4.1/2" Production 3,333 3.958" Surf 4,466' 1D-2-15 2-7/8" Open 4,218' 4,223' 3,910' x 3,821' 10-2-15 2-7/8" Open 4 4,246' 4,256' 3,938' 3,948' 6 1D-2-15 U636-9AX 4,786 UB 38-1 j.. UB 384 2 45 ` US 38-4 E` UB38-4 TD=4,474 MD/4,162'TVD P9D=4,383' MJ/4,075' TVD SCHEMATIC CASING DETAIL Swanson River Field Well: SRU 213-15 API #: 50-133-20652-00 PTD: 215-100 Size Type Wt/Grade/Conn ID Top I Btm 13-3/8" Conductor- Driven 72#/L-80/Weld 12.347" Surf 120 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4.1/2" Production 12.6#/ L-80/ DWC/C HT 3.958" Surf 4,466' JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer, 1.97" ID 3 4,347' x -nipple, 1.875" ID 4 4,256' 10K Dual Ceramic Disc, (intact), 1.995 ID 5 4,258' W LEG, 1.995" ID PERFORATION DETAIL Zone Top (MD) Btm (MD) Top I (TVD Btm (TVD) SPF Date Size Status UB 36-9AX 3,978' 3,998' 3,670' 3,690 1 6 1 4-25-16 2-7/8" Open UB 38-1 4,145' 4,155' 3,837' 3,847' 6 1D-2-15 2-7/8" Open 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Open UB 38-4 4,246' 4,256' 3,938' 3,948' 6 1D-2-15 2-7/8" Isolated 4,336' 4,341' 4,028' 4,033' 6 1 10 -2 -IS 2-7/8" Isolated Updated by DMA 04-25-16 Swanson River Field PROPOSED SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 HilcrorY Alaaka. LLC PTD: 215-100 RKB: M5L=18.90' 7b/8" RA Tag ` depths: 2,932 IF 3333 3821 U2 D3 A 0 3b UB 369X UB 369AX 4,186UB 381 UB 384 2 4'5 UB 36A S! UB 39-4 is i� -D=4.470' MD/4,162' TVD PBD=4,383' MD/4,075' TVD CASING DETAIL Size Type Wt/ Grade/ Conn I ID I Top Btm 13-3/8" Conductor - Driven 72#/L-80/Weld 12.347" Surf 120' 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.6#/L-80/DWC/CHT I 3.958" Surf 4,466' JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer, 1.97" ID 3 4,347' x -nipple, 1.875" ID 4 4,256' IOK Dual Ceramic Disc, (intact), 2.9951D 5 4,258' WLEG, 1.995" ID PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) SPF Date Size Status A7 ±2,787' ±2,792' ±2,496' ±2,501' Proposed TBD ±2,840' ±2,854' ±2,545' ±2,559' Proposed TBD A8 ±2,957' ±2,962' ±2,656' ±2,661' Proposed TBD 62 ±3,145' ±3,151' ±2,838' ±2,843' Proposed TBD ±3,174' ±3,187' ±2,867' ±2,878' Proposed TBD 83 ±3,355' ±3,380' ±3,047' ±3,072' j j Proposed TBD B4 ±3,445' ±3,460' ±3,136' ±3,151' Proposed TBD BS ±3,520' ±3,525' ±3,212' ±3,217' Proposed TBD B6 ±3,705' ±3,710' ±3,396' ±3,401' Proposed T81) UB 13,864' ±3,869' ±3,555' ±3,560' Proposed TBD -36-9X ±3,925' ±3,930' ±3,616' ±3,621' Proposed TBD UB 36-9AK 3,978' • 3,998' 3,670' 3,690' 6 4/25/2016 2-7/8" Open ±4,037' ±4,040' ±3,728' ±3,731' Proposed TBD UB_36-9AX ±4,069' ±4,074' ±3,761' ±3,766' Proposed TBD ±4,109' ±4,114' ±3,801' ±3,806' Proposed TBD ±4,126' ±4,131' ±3,817' ±3,822' Proposed TBD UB 38-1 4,145' r 4,155' 3,837' 3,847' 6 10/2/2015 2-7/8" Open 4,218' 4,223' 3,910' 3,915' 6 10/2/2015 2-7/8" Open UB 38-4 4,246' 4,256' 3,938'3,948' 6 10/2/2015 2-7/8" Isolated 4,336'. 4,341' 4,028' 4,033' 6 1 10/2/2015 2-7/8" Isolated Updated by DMA 02-05-19 10,000,000 1,000,000 s C O 0 100,000 LL u O 10,000 w 0 o n 1,000 u 7 u a N 100 0 0 L 10 HILCORP ALASKA LLC, SWANSON RIV UNIT 213-15 (215-100) SWANSON RIVER, STRLG/U BLUG GS Monthly Production Rates r C , a�aaaaa� a>.aa�� aaaaaaaaa�a�i'rCaa��a� Jan -2015 t Produced Gas (MCFM) . GOR — Produced Water (BOPM) t Produced Oil (BOPM) 10,000,000 100,000 0 0 3 S 10,000 O 1 • 1 Jan -2020 SPREADSHEET_ Prod -inject Curves–Well–VI17-2151000–SRU-213-15-20190212.xlsx 2/12/2019 STATE OF ALASKA • AL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ .rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Install Capstring ❑� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Developmenfl✓ Exploratory ❑ 215-100 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphi❑ Service ❑ 6.API Number: AK 99503 50-133-20652-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028406 Swanson River Unit(SRU)213-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Sterling/Upper Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 4,470 feet Plugs measured N/A RECEIVED true vertical 4,162 feet Junk measured N/A feet JUL y 8 2017 Effective Depth measured 4,383 feet Packer measured 1,981 &4,238 feet true vertical 4,075 feet true vertical 1,807&3,930 fe Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 13-3/8" 120' 120' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner AUGry Perforation depth Measured depth See Attached Schematic SCORED U6 S True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80 4,258'MD 3,950'TVD Baker Swell Pkr, 1,981'MD 1,807'TVD Packers and SSSV(type,measured and true vertical depth) Model D Perm Pkr,N/A 4,238'MD 3,930'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 570 34 0 0 Subsequent to operation: 0 373 38 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Explorator❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL D Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP❑ SPLUG 0 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: 317-190 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerehilcom.com Authorized Signature: �i��" ' #i%- Date: 7/lt//7 Contact Phone: 777-8420 11,,, Form 10-404 Revised 4/2017 �fi. --!( , ,q i' RBDMSbmit Original Only JULJ2 7 2017 g ' • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 50-133-20652-00 215-100 6/4/17 Future Daily Operations: 06/04/2017 -Sunday Rig up dynacoil unit, make up BHA on 3/8" tubing, pressure test line to 2,000psi, pressure up to 3,000psi, test good. RIH w/ BHA to depth of 3,945' KB, pickup to 3,928'KB (pickup weight on line was 1,100#, on depth, set pack-off, clamp capstring to pack-off head, pick injector head, remove capstring from injector. Rig down equipment, secure well, RTP, -.4''' depart location. ,;i k 06/04/2017-Sunday Rig u .dynacoil unit, make up BHA on bing, pressure test line to 2,000psi, press re up to 3,000psi, test good. RIH w BHA t.e'depth of 3,945'KB, pickup to 3, 28'KB (pickup weigh on line wa ,100# on depth, sera -off, clamp cap st • o pack-off head, pick injector head, r ove cap string fro • • ctor. Rig down uipment, secuhe.-well, RTP, depart location. 06/11/2017-Sunday Arrive at Swanson River. Obtain work permit and perform JSA. RU dyna coil unit and reinstall spool. Make up injector head pull cap string out of hole from 3,928'. PU weight was 1,200 lbs. Rig off well and move to the side to run slickline. RU slickline unit. RIH and tag up at 4,001'. 200' high. POOH and RD slickline unit. Decide not to re-run cap string at this time. pct �'-- -' f r' 06/12/2017- Monday ry Arrive on location. Obtain proper permit and perform JSA RU unit and PT to 2,000psi. RIH with 2.5" DD bailer to 4,010'. Work tool and fall down to 4,241'. POOH and work tool out. Tight spot at 4,010'. Gouge marks on bailer barrel. RIH with 2.25" DD bailer to 4,242'. No sign of obstruction. POOH. RIH with 3" LIB to 4,090'. No sign of obstruction. POOH. RIH with 3.75 LIB to 4,010'. WT and get impression. POOH. RD slick line unit and secure location. . 14 • l Swanson River Field SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 IHilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' ; ' CASING DETAIL';1 Size Type Wt/Grade/Conn ID Top Btm r`..i x; Conductor- Driven{ 13-3/8" 72#/L-80/Weld 12.347" Surf 120' s1 lr'^ Driven '»"ra + 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' "A 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' 13-3/8' x.`,1. 7,°7;+ice u ,,il'A, JEWELRY DETAIL ',t 4 ;. ?`.!4 * No Depth Item g, ° y o,r,+ 1 1,981' Baker Swell Packer „x.3-'1 hy.7 2 4,238' Model D Perm Packer,1.97"ID 1, 3 4,347' x-nipple,1.875"ID r54 ;;.`a 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 5 4,258' WLEG,1.995"ID .17,t: 1.7),‘*: SI rwx w,l l �� \ =` e .., ("9 c l7 go* 1.1 „ � PERFORATION DETAIL y 7-5/8" Z4.4''''1.' 17:r. one Top Btm Top Btm SPF Date Size Status (MD) (MD) (TVD) (TVD) 104, RA Tag rd UB 3,978' 3,998' 3,670' 3,690' 6 4-25-16 2-7/8" Open depths: UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Open +4 4 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Open l UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Isolated 2,932 VA 'R. 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated 6s. Ir<, 4 L 3,333' If 3 ' v; *r i+ kt s dY 3,821' r4 P. UB36-9AX r' `9 i` 4,186' li b UB38-1 "iii ,,,y UB 38-4 2 i i 38-4 4/5 UB UB 38-4 14 t 4-1/2"MIXICIE, TD=4,470'MD/4,162'lVD PBTD=4,383'MD/4,075'TVD Updated by DMA 04-25-16 • V OF TFJ� • � THE STATE Alaska Oil and Gas rtv �:—1:4of A LAsKA Conservation Commission _ 333 West Seventh Avenue 1/4 — GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pm* P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager �, .,, 2.017 Hilcorp Alaska, LLC HED ``1.8.`! a 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 213-15 Permit to Drill Number: 215-100 Sundry Number: 317-190 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, p9si_e_vg...._ Cathy '. Foerster Chair DATED this lam' day of May, 2017. RBDMS GL-MAY 1 6 2017 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 0 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Capstring ❑✓ • 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 215-100• 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20652-00 ' 7.If perforating: �)g. 161.78.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.716.Q1 ' Swanson River Unit 213-15 • Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): A028406 • Swanson River/Sterling/Upper Beluga Gas Pool 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): 4,470' . 4,162' . 4,383' 4,075' 1,046 psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 120' 13-3/8" 120' 102' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Swell Pkr;Model D Perm Pkr;N/A 1,981'MD/1,807'ND;4,238'MD/3,930'ND;/N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0• Service 0 14.Estimated Date for 15.Well Status after proposed work: May 24,2017 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q WAG ❑ GSTOR 0 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 � 7 Contact Phone: 777-8420 Authorized Signature: L`/< i Date: 7//o/l7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Ski— \CI0 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ S s 11q Other: Post Initial Injection MIT Req'd? Yes ❑ No EIRBDMS LlrAY ' 6 2017 Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /® ..410r-i iJ /6 APPROVED BY Approved by: r COMMISSIONER THE COMMISSION Date:S-.41*,/ `] ,•ii( ,i/-,, Submit Form and Form 10-403 Revised 4/2017 pp v d p IA0Lvalid for 12 months from the date of approval. Attachments in Duplicate 3774/7 • • Well Prognosis Well: SRU 213-15 FIileorp Alaska, Date:5/7/2016 Well Name: SRU 213-15 API Number: 50-133-20652-00 Current Status: Active Gas Well Leg: N/A Estimated Start Date: May 24, 2017 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-100 First Call Engineer: Ted Kramer (907) 777-8420(0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: 1,414 psi @ 3,685' TVD (Based off of RFT data) Maximum Expected BHP: 1,414 psi @ 3,685' TVD(Based on RFT data) Max. Potential Surface Pressure: 1,046 psi (Based on offset well data and 0.1 psi/ft as gradient to surface) Brief Well Summary SRU 213-15 is completed in the Sterling/Upper Beluga formation. The well is currently making 677 MCFD gas, 50 BWPD at a flowing tubing pressure of 150 psi. The water production in this well is choking off the gas to the V' point that the well cannot sustain steady flow of gas. The purpose of this work is to run a capillary tubing string down the tubing for the purpose of injecting foamer • to aid in lifting the water. Capstring Procedure: (-4-1+ 1. MIRU capillary truck. PT lubricator to 2,500 psi Hi 250 Low. -- 2. Install wellhead packoff. a. Current tree cap is 4.5" Otis w/4-1/16" 5K flanged connections. 3. PU 3/8" capillary string. RIH and set the bottom at 3,928' (50' (+/-) above the top perforation at 3,978'). 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 3. Wellhead Diagram • • • Swanson River Field II SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 ua,�,1„_ll:�,>:i.IAA PTD: 215-100 RKB:MSL=18.90' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor- 72#/L-80/Weld 12.347" Surf 120' Driven 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' 13-3/8'4 k ? a JEWELRY DETAIL No Depth Item i 1 1,981' Baker Swell Packer r' µ!1 2 4,238' Model D Perm Packer,1.97"ID 3 4,347' x-nipple,1.875"ID 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID • 5 4,258' WLEG,1.995"ID a; /1 4 C� 1 PERFORATION DETAIL 7-5/8,. 4 "' Zone Top Btm Top Btm (MD) (MD) (ND) (ND) SPF Date Size Status RA Tag UB 36-9AX 3,978' . 3,998' 3,670' 3,690' 6 4-25-16 2-7/8" Open depths: UB 38-1 4,145' • 4,155' • 3,837' 3,847' 6 10-2-15 2-7/8" Open 4,218' • 4,223' • 3,910' 3,915' 6 10-2-15 2-7/8" Open 932 a UB 38-4 4,246' • 4,256' . 3,938' 3,948' 6 10-2-15 2-7/8" Isolated 24,336' • 4,341' • 4,028' 4,033' 6 10-2-15 2-7/8" Isolated 3.333' °0 aa21' Q U3 36-9AX 4,186' 0 U838-1 a UB 38-4 2 4/5 � UB 38-4 UB 38-4 41/2' A ► TD=4,470'MD/4,162'7VD PBTD=4,383'MD/4,075'TVD Updated by DMA 04-25-16 0 Swanson River Field Ili PRO OSED SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 Hilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor- 72#/L-80/Weld 12.347" Surf 120' .. Driven 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' • 133/8'"A t' .� JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer,1.97"ID w/20'2-3/8"tail pipe e„ 3 4,347 x-nipple,1.875"ID 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 10,o, 5 4,258' WLEG,1.995"ID 7 5/8' a 'A ',,-* tt,,::z RA Tag 4)., Capillary String Proposed to Install depths: '# 3/8" 2205 Stainless Steel Top Bottom MD 0' 3,928' TVD 0' 3,620' 2,932' 0 r71 ri? l ,' ,, 1 s4 t to t t*, PERFORATION DETAIL 3,333' '6 / Top Btm Top Btm Zone (MD) (MD) (TVD) (TVD) SPF Date Size Status UB 36-9AX 3,978' 3,998' 3,670' 3,690' 6 4-25-16 2-7/8" Open t . UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Open 4 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Open 3,821' UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Isolated '"•• -a UB36-9AX 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated 4,186' © --a UB 38-1 4 UB 38-4 2 `I 4/5 t:-127_.- - UB384 ly* UB 38-4 '44# *i 41/2" -,.4-kle TD=4,470'MD/4,162'DID PBTD=4,383'MD/4,075'ND Updated by DMA 05-09-17 ._ • • .. H Swanson River Unit SRU 213-15 05/04/2017 Iailrorp %Iv.krs.LI.(: Swanson River Casing hanger,CW,11 x 4'/: SRU 213-15 DWC/C box btm x 6.125"RH 13 3/8 x 7 5/8 x 4''/: stub acme box top,w/7 5/8 od neck,4"type H BPV profile,DD-NL material BHTA,Otis,4 1/16 5M FE x 6.5 Otis quick union top t . Valve,Swa b,WKM-M tiW 41/165M FE,HWO, ' EE trim �' Valve,SSV,WKM-M, Valve,Wing,WKM-M, 31/85M FE,w/Hydraulic X SEE_alli in 3 1/8 5M FE,HWO, operator ?F71:477V EE trim !-:•47, ,•-,Nqk":gigilp 1:,-.04.IT '''",-Oviirq10.1-.;-::,. 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C7/N u') O.O 4 E r o y 8 I _ = N C1111 CO2 f0 rt 'I O F E o. �� Vs °M/� O 11 CO N c cn a) V/ Tj 1 N N C C- 0 C 0 1� 03 Q = 5 N iiiU a Q CO 03 ci E ' a� 8 N O ZaI £ 0 C ° 2 0 II co (0 0 I Z (o d N co co 0 0 E a o O a) Z N V To TO a i 1, G 11 NI 0) m m l6 N o a b 0 L ° E 0 r. �C J1 C O I O0 ~ Lc) Lo Lo Lo 1 m N- m COrm = >_ f6 I IX a CO w E a 0 r a) N (O CO CO N in W wp 0 W 1. d r N N N N O. N c 1 re p C N _ > rt ta R ' 0 ct z ca a 0 0 LLI a) 9 0) ON. N Z� p C F I6 Z = @ C 111 N V O d Q o Q o ° 11' C C L) �', 0 U U U O �', 2 •N- U m J .N N .a N R U h 0 a O Q N W E E E U - N Q °' 0 o ° w 3 z c i a C� 00 c.) ° 00 00 a � I S OF Ti�wV� / � THE STATE gP� 11 y, Alaska Oil and Gas N44 Z� Ath ALAsKA Conservation Commission f t 2_`_• 5 333 West Seventh Avenue l', r: ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `' Main: 907.279.1433 OF ALAS Fax:Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 213-15 Permit to Drill Number: 215-100 Sundry Number: 316-324 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, C-47 /°;CathyFoerster 67714 Chair DATED this�73ay of June, 2016. RBDMS (, /JUN 1 3 2016 • • STATE OF ALASKA JU O 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ,8 g /4 APPLICATION FOR SUNDRY APPROVALS A Cr 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations o Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate E Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 . 215-100 " 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20652-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.716 " Swanson River Unit(SRU)213-15 Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10. Field/Pool(s): A028406 " Swanson River/Sterling/Upper Beluga Gas Pod - 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): 4,470' 4,162' 4,383' 4,075' 1,071 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 120' 13-3/8" 120' 102' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6#/L-80 4,258 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Swell Pkr; Model D Perm Pkr;N/A 1,981'MD/1,807'TVD;4,238'MD/3,930'TVD:/N/A 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: June 21,2016 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS [A • 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 �rl� Phone 907-777-8405 Date q.7/iC COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \L - 32J-( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ �^ IA/ JUN �O�6 JUN Spacing Exception Required? Yes ❑ No © Subsequent Form Required: / 0 Y RBDMS o"-1V /� 1)9g...÷4/....., APPROVED BY /Approved by:C COMMISSIONER THE COMMISSION Date: 6 - c 4.... `Z"'/cc, Submit Form and Form 10-403 Revised 11/2015 OeG a AlLor 12 months abm the date of approval. Attachments in Dupli ate • • Well Prognosis • Well: SRU 213-15 Hilcora Alaska,LLC Date:6/7/2016 Well Name: SRU 213-15 API Number: 50-133-20652-00 Current Status: Active Gas Well Leg: N/A Estimated Start Date: June 21st, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-100 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: 1,275 psi @ 3,675' TVD (Extrapolated from recent well work data) Maximum Expected BHP: 1,411 psi @ 3,404' TVD(Based on offset well data from SRU 241-16) Max. Potential Surface Pressure: 1,071 psi (Based on offset well data and 0.1 psi/ft gas gradient to surface) Brief Well Summary SRU 213-15 was drilled as a Grass roots monobore completion in 2015 to target gas sands in the Sterling/Upper Beluga formations. In October 2015, 2 zones were perforated in 4 different sands. The well began to make water,so a packer with a ceramic disk were installed.The well currrently produces 2.3 MMscfd and 2 bbl of • water. The purpose of this work/sundry is to add perforations in the Sterling/Upper Beluga formation. Notes Regarding Wellbore Condition • Plan to tag/drift with slickline before running E-line. • Prior to a setting a plug (contingency),then water will be pushed away with gas production or well swabbed down. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RU 2-7/8" 6 spf wireline guns. 3. RIH and perforate the following intervals and test zones individually: • Zone Sands (MD) Btm (MD) FT SPF Sterling/Upper Beluga UB B4 ±3,445' ±3,474' 29' 6 Sterling/Upper Beluga UB B5 ±3,520' ±3,535' 15' 6 Sterling/Upper Beluga UB B6 ±3,702' ±3,720' 18' 6 Sterling/Upper Beluga UB 36-9A2 ±3,923' ±3,932' 9' 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Coorelation Log. d. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. e. Install Crystal gauges. Record tubing pressures before and after each perforating run. . 11 • • Well Prognosis • Well: SRU 213-15 Hilcorp Alaska,LLC Date:6/7/2016 f. All perforations in table above are located in the Sterling/Upper Beluga Pool based on Conservation Order No. 716. 4. RD E-line. 5. Turn well over to production. E-line Procedure(Contingency): 6. If any zone produces sand and/or water or needs isolated 7. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. a. SITP will be+/- 1,200 psi (remaining gas). 8. RIH and set 4-1/2" CIBP at depth above zone. 9. RU dump bailer. RIH with cement and dump bail 35' of cement on CIBP. POOH. 10. Continue with steps 2-5. Or 11. RIH and set 4-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • . Swanson River Field SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 Hilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL a _Size Type Wt/Grade/Conn ID Top Btm • 13-3/8" Conductor- 72#/L-80/Weld 12.347" Surf 120' Driven _ 7-5/8" Surface 29.78/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.68/L-80/DWC/C HT 3.958" Surf 4,466' 13-3/8" JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer,1.97"ID • 3 4,347' x-nipple,1.875"ID 4 _ 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 5 4,258' WLEG,1.995"ID " S Er i PERFORATION DETAIL 7-5/8" 41.. I Zone Top Btm Top Btm SPF Date Size Status (MD) (MD) (TVD) (TVD) RA Tag UB 36-9AX 3,978' 3,998' 3,670' 3,690' 6 4-25-16 2-7/8" Open depths: UB38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Open 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Open UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Isolated 2,932 D - - 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated 3,333 `: 0 ki ,11 1.$ 3,821' U8 36-9AX s r 4,186' a C UB38-1 2 '?, ii UB38-4 4/5 ..+� UB38-4 UB 38-4 .4 y, 41/2"'Ai ,....' . TD=4,470'MD/4,162'TVD MID=4,383'MD/4,075'TVD Updated by DMA 04-25-16 . Swanson River eld PROPOSED SCHEMATIC Well: SRU213-1Fi5 f API #: 50-133-20652-00 Hilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL �'S �,,.,1i', Size Type Wt/Grade/Conn ID Top Btm a �+I � •� Conductor- 1 Driven 13 3/8" 72#/L-80/Weld 12.347" Surf 120' ),, ?`•""� Driven r 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' .,,, 13-3/8" ; � JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer,1.97"ID 3 4,347' x-nipple,1.875"ID 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 5 4,258' WLEG,1.995"ID f •' Z 1 PERFORATION DETAIL 41 7-5/g' I Zone Top Btm Top Btm SPF Date Size Status (MD) (MD) (TVD) (TVD) RA Tag UB B4 ±3,445' ±3,474' ±3,137 ±3,166 6 TBD 2-7/8" Proposed depths: ' UB B5 ±3,520' ±3,535' ±3,212 ±3,227 6 TBD 2-7/8" Proposed • UB B6 ±3,702' ±3,720' ±3,394 ±3,412 6 TBD 2-7/8" Proposed UB 36-9A2 ±3,923' ±3,932' ±3,615 ±3,624 6 TBD 2-7/8" Proposed 2,932' D 4 UB 36-9AX 3,978' 3,998' 3,670' 3,690' 6 4-25-16 2-7/8" Open -1•,,', UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Open 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Open 3333' CI UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Isolated 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated BB4 BB5 BB6 3,821' a A p UB 36-9A2 UB 36-9AX 4,186 ` UB38-1 UB 38-4 2 i 4/5 UB 38-4 UB 38-4 14 4-1/2"404411.41P 1D=4,470'Mo/4,162'1VD PBTD=4,383'MD/4,075'TW Updated by DMA 06-07-16 • • 2 1 5 1 0 0 II Seth Nolan Hilcorp Alaska, LLC 2 77 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 lr,irorri, u:t.k:,.1.ts, Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED 5 *42014 K BENDER DATE 05/19/2016 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 1VitiY 2 0 CU ib 333 W 7th Ave Ste 100 A n Anchorage, AK AOGCC 99501 DATA TRANSMITTAL SRU 213-15 Perforation Log prints and data Prints: Perforation Record Log CD: 1 Electric logs a SRU_213-15_PERF_25APP16.pdf 5,/13120169:21 AM PDF Document 984 KB SRU 213-15 PERF 25APR16 CORREL.ATI... 5113/20169:21 AM LAS File 96 KB SRU_213-15_PERF_25APP16_img.tif 5/13,/20169:21 AM TIF File 1522 KB SRU 213-15 PERF 25APR16 SHOOTING ,,. 5/13,/20169:21 AM LAS File 72 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 907 777.8337 Receivedy: Date: • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, May 06, 2016 8:38 AM To: 'Monty Myers' Subject: RE: SRU 215-13 (PTD 215-100) Cementing info Monty, The info provided by you is sufficient ..just want the record to be complete. I will add this email and report to the file. You don't need to resubmit the 10-407 . I will hand write in the CBL/PNL logs. In future make sure they are included. Regards, 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: Monty Myers [mailto:mmyers@rhilcorp.com] Sent: Thursday, May 05, 2016 5:00 PM To: Schwartz, Guy L (DOA) Subject: RE: SRU 215-13 (PTD 215-100) Good afternoon Guy, The 43 bbls of tail were pumped in the well, however the comments that were submitted to you, must have been erased or missed in our well reporting system. The attached document is Schlumberger's pump schedule of the job that has the 43 bbls listed in the details of the operation. My apologies for the confusion on this. Would you like us to re-submit the daily log with updated comments?Also,do we need to mark box 22 of a new 10-407 and re-submit it to you? Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 28, 2016 10:55 AM 1 To: Monty Myers Subject: SRU 215-13 (PTD 215-100) Monty, Looking at this 10-407 also. 1) The surface casing daily report summary doesn't specify that the 43 bbl of tail cement was ever pumped. Can you verify that? It is listed on the spreadsheet cmt report ... 2) CBL and PNL were not listed in Box 22 3) The CBL VDL sucks... maybe should have this rerun for free by Halliburton. Something was wrong with the 5' waveform for most of the log. Amplitude for 3' is ok. 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(Guy.schwartz@alaska.gov). 2 Schiumberger S Cementing Ja Report CemCATv1.4 Well SRU213-15 Client Hilcorp Field Swanson River SIR No. C2XM-00138 Engineer H Kent Griggs Job Type Surface Country United States Job Date 09-14-2015 Time Pressure Density Rate Messages 14/3015 01:25: 02:25:08 Start Job ' begin priming pump 02:40:00 prejob safety meeting 02:55:00 Reset Total,Vol=12.93 bbl 03:10:00 begin pumping water to dear lines begin pressure test begin high PT 03:25:00 rig to pump 35bbls mudPUSH II begin batching lead cmt • mudscale verify density Reset Total,Vol=30.11 bbl 03:40:00 L begin pumping lead 12 ppg cement adding 1ppb CemNET mudpush at shoe 03:55:00 Lead cement at shoe 157.4 bbls lead oumoed 04:10:00 begin batching tail cement Reset Total,Vol=315.63 bbl 43 bbls tail oumoed 04:25:00 1 ( Reset Total,Vol=86.02 bbl L( r pump water to flush lines swapping to mud for displacement • pumped 10bbls water cement in the cellar • 04:40:00 • • • • 112 bbls pumped on displacement 04:55:00 bleed off pressure/check floats .5 bbls return/floats holding 05:10:00 05:23:36 End Job hh:mm:ss 0.00 1000 2000 3000 0000 5000 5.0 10.0 15.0 20.0 25.0 0.00 2.5 5.0 7.5 10.0 ov14=015 05:13:n — PSI LB/G B/M 09/14/2015 15:07:33 i • Schlumberger Cementing Service Report Customer Job Number Hilcorp C2XM-00138 Well Location(legal) Schlumberger Location Job Start SRU213-15 SRU213-15 PAK Sep/14/2015 Field Formation Name/Type Deviation Bit Size Well MD Well TVD Swanson River Clean-Sandstone 32 deg 9.9 In 2538.0 R 2248.0 ft County Kenai State/Province Alaska BHP BHST BHCT Pore Press.Gradient Well Master API/UWI 1111 psi 70 degF 68 degF lb/gal Rig Name Drilled For Service Via Casing/Liner Saxon 169 Gas Land Depth,ft Size,in Weight,lb/ft Grade Thread Offshore Zone Well Class Well Type 2538.0 7.6 29.7 N80 BUTT New Development 0.0 0.0 0.0 Drilling Fluid Type Max.Density Plastic Viscosity Tubing/Drill Pipe Bentonite lb/gal CP T/D Depth,ft Size,in Weight,lb/ft Grade Thread Service Line Job Type Cementing Surface Max.Allowed Tub.Press Max.Allowed Ann.Press WH Connection Perforations/Open Hole 750 psi psi Double Cement head Top,ft Bottom,ft shot/ft No.of Shots Total Interval Service Instructions ft ft ft 7 5/8 Surface Casing CPT ft ft Diameter ABT ft ft In Silo x 2 Treat Down Displacement Packer Type Packer Depth Casing 112.0 bbl None ft Tubing Vol. Casing Vol. Annular Vol. Openhole Vol. bbl 115.0 bbl bbl bbl Casing/Tubing Secured ❑ 1 Hole Vol.Circulated prior to Cement ❑ Casing Tools Squeeze Job Uft Pressure psi Shoe Type Float Squeeze Tyne Pipe Rotated ❑ Pipe Reciprocated x❑ Shoe Depth 2538.0 ft Tool Tyne No.Centralizers 30 Top Plugs 1 Bottom Plugs 1 Stage Tool Type Tool Depth ft Cement Head Type Double Stage Tool Depth ft Tall Pipe Size in Job Scheduled For Arrived on Location Leave Location Collar Type Float Tall Pipe Depth ft Sep/14/2015 03:00 Sep/13/2015 23:00 Sep/14/2015 06:00 Collar Depth 2458.0 ft Sqz.Total Vol. bbl Date Time Pressure Density CMT RATE CMT_VOL Message 24-hr PSI LB/G B/M BBL dock 09/14/2015 02:25:08 20 8.26 2.3 0.0 Started Acquisition 09/14/2015 02:25:18 20 8.26 2.3 0.4 Start Job 09/14/2015 02:25:38 18 0.04 0.8 0.9 09/14/2015 02:26:08 20 8.26 2.8 2.3 09/14/2015 02:26:38 19 0.01 0.7 2.6 09/14/2015 02:27:08 20 8.27 2.7 3.8 09/14/2015 02:27:38 21 8.26 2.9 4.7 09/14/2015 02:27:46 20 8.26 2.9 5.1 begin priming pump 09/14/2015 02:28:08 21 8.26 0.0 5.7 09/14/2015 02:28:38 21 8.27 0.0 5.7 09/14/2015 02:29:08 20 8.26 0.0 5.7 09/14/2015 02:29:38 20 8.04 0.3 5.8 09/14/2015 02:30:08 20 7.58 0.3 6.0 09/14/2015 02:31:08 20 8.11 0.3 6.2 09/14/2015 02:31:38 20 8.07 0.3 6.3 09/14/2015 02:32:08 19 7.99 0.1 6.4 09/14/2015 02:32:38 19 8.07 0.0 6.5 09/14/2015 02:33:08 20 8.13 0.0 6.5 09/14/2015 02:33:38 20 8.09 0.0 6.5 09/14/2015 02:34:08 20 8.15 0.0 6.5 09/14/2015 02:34:38 20 8.14 0.0 6.5 Page 1 of Well Job Start Customer Fief Job Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Time Pressure Density CMT_RATE CMT_VOL Message 24-hr PSI LB/6 B/M BBL dock 09/14/2015 02:35:38 20 8.16 0.0 6.5 09/14/2015 02:36:08 21 8.17 0.0 6.5 09/14/2015 02:36:38 20 8.16 0.0 6.5 09/14/2015 02:37:08 20 8.19 0.0 6.5 09/14/2015 02:37:38 20 8.13 0.0 6.5 09/14/2015 02:38:08 21 8.18 0.0 6.5 09/14/2015 02:38:38 20 8.20 0.0 6.5 09/14/2015 02:39:08 21 8.20 0.0 6.5 09/14/2015 02:39:38 20 8.20 0.0 6.5 09/14/2015 02:40:08 21 8.21 0.0 6.5 prejob safety meeting 09/14/2015 02:40:38 20 8.22 0.0 6.5 09/14/2015 02:41:08 21 8.22 0.0 6.5 09/14/2015 02:41:38 21 8.21 0.0 6.5 09/14/2015 02:42:08 20 8.22 0.0 6.5 09/14/2015 02:42:38 20 8.22 0.0 6.5 09/14/2015 02:43:08 20 8.22 0.0 6.5 09/14/2015 02:43:38 20 8.23 0.0 6.5 09/14/2015 02:44:08 20 8.21 0.0 6.5 09/14/2015 02:44:38 21 8.22 0.0 6.5 09/14/2015 02:45:38 20 8.22 0.0 6.5 09/14/2015 02:46:08 21 8.23 0.0 6.5 09/14/2015 02:46:38 21 8.23 0.0 6.5 09/14/2015 02:47:08 20 8.22 0.0 6.5 09/14/2015 02:47:38 21 8.22 0.0 6.5 09/14/2015 02:48:08 21 8.22 0.0 6.5 09/14/2015 02:48:38 20 8.24 0.0 6.5 09/14/2015 02:49:08 21 8.23 0.0 6.5 09/14/2015 02:49:38 21 8.23 0.0 6.5 09/14/2015 02:50:08 21 8.23 0.0 6.5 09/14/2015 02:50:38 21 8.23 0.0 6.5 09/14/2015 02:51:08 21 8.22 0.0 6.5 09/14/2015 02:51:38 20 8.23 0.0 6.5 09/14/2015 02:52:08 20 8.23 0.0 6.5 09/14/2015 02:52:38 20 8.22 0.0 6.5 09/14/2015 02:53:08 21 8.23 0.0 6.5 09/14/2015 02:53:38 20 8.23 0.0 6.5 09/14/2015 02:54:08 20 8.22 0.0 6.5 09/14/2015 02:54:38 21 8.23 0.0 6.5 09/14/2015 02:55:08 20 8.22 0.0 6.5 09/14/2015 02:55:38 20 8.24 0.0 6.5 09/14/2015 02:56:08 20 8.24 0.0 6.5 09/14/2015 02:56:38 20 8.23 0.0 6.5 09/14/2015 02:57:08 20 8.23 0.0 6.5 09/14/2015 02:57:38 21 8.23 0.0 6.5 09/14/2015 02:58:08 21 8.22 0.0 6.5 09/14/2015 02:58:38 20 8.23 0.0 6.5 09/14/2015 02:59:08 20 8.22 0.0 6.5 09/14/2015 02:59:38 21 8.23 0.0 6.5 09/14/2015 03:00:08 20 8.22 0.0 6.5 09/14/2015 03:00:38 20 8.23 0.0 6.5 09/14/2015 03:01:08 20 8.23 0.0 6.5 09/14/2015 03:01:26 19 8.23 0.0 6.5 Reset Total,Vol=12.93 bbl 09/14/2015 03:01:38 20 8.23 0.0 0.0 09/14/2015 03:02:08 20 8.23 0.0 0.0 Page 2 of B • Well Field lob Start Customer • 3ob Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Tim* Pressure Density CMT RATE CMT VOL Message 24-hr PSI LB/G B/M BBL dock 09/14/2015 03:03:08 20 8.23 0.0 0.0 09/14/2015 03:03:38 21 8.23 0.0 0.0 09/14/2015 03:04:08 21 8.23 0.0 0.0 09/14/2015 03:04:38 20 8.23 0.0 0.0 09/14/2015 03:05:08 21 8.22 0.0 0.0 09/14/2015 03:05:38 20 8.24 0.0 0.0 09/14/2015 03:06:08 21 8.24 0.0 0.0 09/14/2015 03:06:38 20 8.24 0.0 0.0 09/14/2015 03:07:08 20 8.25 0.0 0.0 09/14/2015 03:07:38 21 8.25 0.0 0.0 09/14/2015 03:08:08 21 8.25 0.0 0.0 09/14/2015 03:08:36 21 8.25 0.0 0.0 begin pumping water to clear lines 09/14/2015 03:08:38 21 8.24 0.0 0.0 09/14/2015 03:09:08 21 8.22 0.0 0.0 09/14/2015 03:09:38 21 8.20 0.0 0.0 09/14/2015 03:10:08 21 8.21 0.0 0.0 09/14/2015 03:10:38 21 8.23 0.0 0.0 09/14/2015 03:11:08 73 8.24 2.1 0.3 09/14/2015 03:11:38 146 8.24 2.6 1.5 09/14/2015 03:12:08 132 8.22 2.6 2.8 09/14/2015 03:12:38 172 8.22 3.6 4.2 09/14/2015 03:13:08 160 8.24 3.8 6.1 09/14/2015 03:13:38 159 8.26 3.8 8.0 09/14/2015 03:14:08 152 8.24 3.8 9.9 09/14/2015 03:14:38 181 8.26 3.8 11.9 09/14/2015 03:15:08 176 8.26 - 3.8 13.8 09/14/2015 03:15:31 89 8.27 0.0 14.9 begin pressure test 09/14/2015 03:15:38 77 8.27 0.0 14.9 09/14/2015 03:16:08 39 8.27 0.0 14.9 09/14/2015 03:16:38 31 8.20 0.0 14.9 09/14/2015 03:17:08 29 8.28 0.0 14.9 09/14/2015 03:17:38 28 8.28 0.0 14.9 09/14/2015 03:18:08 1216 8.29 0.0 15.0 09/14/2015 03:18:38 1027 8.28 0.0 15.0 09/14/2015 03:19:02 980 8.28 0.0 15.0 begin high PT 09/14/2015 03:19:08 972 8.28 0.0 15.0 09/14/2015 03:19:38 951 8.28 0.0 15.0 09/14/2015 03:20:38 4811 8.28 0.0 15.1 09/14/2015 03:21:08 4755 8.27 0.0 15.1 09/14/2015 03:21:38 4707 8.28 0.0 15.1 09/14/2015 03:22:08 3976 8.28 0.0 15.1 09/14/2015 03:22:38 47 8.28 0.0 15.1 09/14/2015 03:23:08 39 8.27 0.0 15.1 09/14/2015 03:23:38 38 8.27 0.0 15.1 09/14/2015 03:24:08 38 8.27 0.0 15.1 09/14/2015 03:24:16 38 8.28 0.0 15.1 rig to pump 35bbls mudPUSH II 09/14/2015 03:24:38 37 8.28 0.0 15.1 09/14/2015 03:25:08 39 8.28 0.0 15.1 09/14/2015 03:25:38 40 8.28 0.0 15.1 09/14/2015 03:26:08 39 8.28 0.0 15.1 09/14/2015 03:26:38 39 8.28 0.0 15.1 09/14/2015 03:27:08 39 8.28 0.0 15.1 09/14/2015 03:27:38 38 8.27 0.0 15.1 09/14/2015 03:28:08 37 8.28 0.0 15.1 Page 3 of8 Well Fief Job Start Customer 3ob Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Time Pressure Density CMT RATE CMT VOL Message 24-hr PSI LB/D B/M BBL clock 09/14/2015 03:29:07 36 8.27 0.0 15.1 begin batching lead cmt 09/14/2015 03:29:08 35 8.26 0.0 15.1 09/14/2015 03:29:38 36 9.62 0.0 15.1 09/14/2015 03:30:08 35 11.45 0.0 15.1 09/14/2015 03:30:38 35 12.01 0.0 15.1 09/14/2015 03:31:08 35 12.03 0.0 15.1 09/14/2015 03:31:38 34 11.92 0.0 15.1 09/14/2015 03:32:08 33 12.01 0.0 15.1 09/14/2015 03:32:38 33 12.06 0.0 15.1 09/14/2015 03:33:08 32 12.08 0.0 15.1 09/14/2015 03:33:35 31 12.08 0.0 15.1 mudscale verify density 09/14/2015 03:33:38 32 12.08 0.0 15.1 09/14/2015 03:34:08 32 12.08 0.0 15.1 09/14/2015 03:34:38 31 12.08 0.0 15.1 09/14/2015 03:35:08 30 12.07 0.0 15.1 09/14/2015 03:35:38 31 12.08 0.0 15.1 09/14/2015 03:36:08 29 12.06 0.0 15.1 09/14/2015 03:36:38 28 12.07 0.0 15.1 09/14/2015 03:37:08 28 12.08 0.0 15.1 09/14/2015 03:37:29 28 12.06 0.0 15.1 Reset Total,Vol=30.11 bbl 09/14/2015 03:37:38 27 12.07 0.0 0.0 09/14/2015 03:37:45 26 12.07 0.0 0.0 begin pumping lead 12 ppg cement 09/14/2015 03:38:08 404 11.82 5.1 0.9 09/14/2015 03:38:38 355 11.72 5.1 3.5 09/14/2015 03:39:08 383 11.63 5.1 6.0 09/14/2015 03:39:38 255 12.31 5.1 8.6 09/14/2015 03:40:08 364 12.52 5.4 11.2 09/14/2015 03:40:16 367 12.55 5.3 11.9 adding 1ppb CemNET 09/14/2015 03:40:38 326 12.52 5.4 13.9 09/14/2015 03:41:08 362 12.93 5.4 16.6 09/14/2015 03:41:38 349 12.16 5.4 19.3 09/14/2015 03:42:08 250 11.87 5.4 22.0 09/14/2015 03:42:38 271 11.29 5.4 24.6 09/14/2015 03:43:08 292 11.81 5.4 27.3 09/14/2015 03:43:38 253 12.35 5.3 30.0 09/14/2015 03:44:08 289 11.70 5.4 32.7 09/14/2015 03:44:38 245 11.25 5.4 35.4 09/14/2015 03:45:08 251 11.51 5.4 38.1 09/14/2015 03:45:38 251 11.58 5.4 40.8 09/14/2015 03:46:08 270 11.57 5.4 43.5 09/14/2015 03:46:38 266 11.71 5.4 46.2 09/14/2015 03:47:08 253 11.80 5.4 48.8 09/14/2015 03:47:38 206 12.37 5.4 51.5 09/14/2015 03:48:08 252 12.64 5.4 54.2 09/14/2015 03:48:38 295 12.40 5.4 56.9 09/14/2015 03:49:08 260 12.27 5.4 59.6 09/14/2015 03:49:38 270 12.19 5.6 62.4 09/14/2015 03:50:08 313 12.11 5.6 65.2 09/14/2015 03:50:38 317 12.10 5.6 68.0 09/14/2015 03:51:08 261 12.05 5.6 70.8 09/14/2015 03:51:38 255 12.02 5.6 73.6 09/14/2015 03:52:08 290 11.93 5.6 76.5 09/14/2015 03:52:09 235 11.93 5.6 76.5 mudpush at shoe 09/14/2015 03:52:38 301 11.53 5.6 79.3 Page 4 of 8 • Well Field Job Start Customer • Job Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Time Pressure Density CMT_RATE CMT VOL Message 24-hr PSI LB/C B/M BBL dock 09/14/2015 03:53:38 246 12.05 5.6 84.9 09/14/2015 03:54:08 269 12.21 5.6 87.7 09/14/2015 03:54:38 273 12.42 5.6 90.5 09/14/2015 03:55:08 309 12.62 5.6 93.3 09/14/2015 03:55:38 295 12.10 5.6 96.1 09/14/2015 03:56:08 256 11.94 5.6 98.9 09/14/2015 03:56:38 219 11.83 5.6 101.7 09/14/2015 03:57:08 265 12.06 5.6 104.5 09/14/2015 03:57:38 221 11.92 5.7 107.4 09/14/2015 03:58:08 237 11.97 5.6 110.2 09/14/2015 03:58:38 282 12.12 5.6 113.0 09/14/2015 03:59:04 267 11.88 5.6 115.4 Lead cement at shoe 09/14/2015 03:59:08 256 11.81 5.6 115.8 09/14/2015 03:59:38 261 11.76 5.6 118.6 09/14/2015 04:00:08 282 12.59 5.6 121.4 09/14/2015 04:00:38 291 12.17 5.6 124.2 09/14/2015 04:01:08 245 12.31 5.6 127.0 09/14/2015 04:01:38 239 12.36 5.6 129.8 09/14/2015 04:02:08 199 11.93 5.6 132.6 09/14/2015 04:02:38 221 11.98 5.6 135.5 09/14/2015 04:03:08 251 12.31 5.6 138.3 09/14/2015 04:03:38 222 11.72 5.6 141.1 09/14/2015 04:04:08 235 12.26 5.6 143.9 09/14/2015 04:04:38 245 12.26 5.6 146.7 09/14/2015 04:05:08 235 12.56 5.6 149.5 09/14/2015 04:05:38 273 11.46 5.6 152.3 09/14/2015 04:06:08 256 11.91 5.6 155.1 09/14/2015 04:06:38 55 0.66 0.0 157.4 09/14/2015 04:06:48 45 0.38 0.0 157.4 157.4 bbls lead pumped 09/14/2015 04:07:08 33 0.31 0.0 157.4 09/14/2015 04:07:38 28 0.29 0.0 157.4 09/14/2015 04:08:08 25 0.29 0.0 157.4 09/14/2015 04:08:38 23 0.30 0.0 157.4 09/14/2015 04:08:41 23 0.30 0.0 157.4 begin batching tail cement 09/14/2015 04:09:08 23 0.30 0.0 157.4 09/14/2015 04:09:38 22 0.30 0.0 157.4 09/14/2015 04:10:08 21 0.29 0.0 157.4 09/14/2015 04:10:38 21 3.91 0.0 157.4 09/14/2015 04:11:08 22 8.75 0.0 157.4 09/14/2015 04:11:38 23 12.38 0.0 157.4 09/14/2015 04:12:08 24 14.75 0.0 157.4 09/14/2015 04:12:38 23 15.22 0.0 157.4 09/14/2015 04:13:08 23 15.44 0.0 157.4 09/14/2015 04:13:38 23 15.45 0.0 157.4 09/14/2015 04:13:54 142 15.40 4.3 157.8 Reset Total,Vol=315.63 bbl 09/14/2015 04:14:08 242 14.15 4.3 1.0 09/14/2015 04:14:38 225 13.83 4.3 3.1 09/14/2015 04:15:08 451 15.09 5.7 5.7 09/14/2015 04:15:38 503 15.68 5.7 8.5 09/14/2015 04:16:08 499 15.22 5.6 11.3 09/14/2015 04:16:38 382 14.96 5.6 14.1 09/14/2015 04:17:08 521 15.16 5.6 16.9 09/14/2015 04:17:38 278 15.02 5.6 19.7 09/14/2015 04:18:08 347 15.38 5.6 22.5 Page 5 of 8 Well Job Start Customer Fief Job Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Time Pressure Density CMT MTE CMT VOL Message 24-hr PSI LB/6 B/M BBL clock 09/14/2015 04:19:08 425 15.31 5.6 28.1 09/14/2015 04:19:38 313 15.51 5.6 30.9 09/14/2015 04:20:08 577 15.77 5.6 33.7 09/14/2015 04:20:38 485 15.37 5.6 36.5 09/14/2015 04:21:08 318 15.35 5.6 39.3 09/14/2015 04:21:38 126 15.86 1.8 42.0 09/14/2015 04:22:08 45 15.84 0.0 42.7 09/14/2015 04:22:38 30 15.86 0.0 43.0 09/14/2015 04:22:44 27 15.86 0.0 43.0 43 bbls tail pumped 09/14/2015 04:23:08 24 15.85 0.0 43.0 09/14/2015 04:23:38 24 15.92 0.0 43.0 09/14/2015 04:24:08 22 15.94 0.0 43.0 09/14/2015 04:24:36 23 15.94 0.0 43.0 Reset Total,Vol=86.02 bbl 09/14/2015 04:24:38 23 15.94 0.0 0.0 09/14/2015 04:24:55 174 13.30 2.8 0.1 pump water to flush lines 09/14/2015 04:25:08 196 8.35 5.4 1.1 09/14/2015 04:25:38 229 8.34 5.4 3.9 09/14/2015 04:26:08 262 8.34 5.4 6.6 09/14/2015 04:26:38 237 8.34 5.4 9.3 09/14/2015 04:27:00 31 8.34 0.0 9.9 swapping to mud for displacement 09/14/2015 04:27:08 29 8.34 0.0 9.9 09/14/2015 04:27:35 20 8.34 0.0 9.9 pumped 10bbls water 09/14/2015 04:27:38 20 8.34 0.0 9.9 09/14/2015 04:28:08 225 8.85 5.1 11.6 09/14/2015 04:28:38 366 8.78 5.1 14.2 09/14/2015 04:29:08 374 8.69 5.1 16.7 09/14/2015 04:29:38 224 8.68 5.1 19.3 09/14/2015 04:30:08 436 9.10 5.1 21.8 09/14/2015 04:30:38 266 9.10 5.1 24.4 09/14/2015 04:31:08 331 9.10 5.1 26.9 09/14/2015 04:31:38 305 9.09 5.1 29.5 09/14/2015 04:32:08 328 9.17 5.1 32.0 09/14/2015 04:32:38 336 9.17 5.1 34.6 09/14/2015 04:33:08 308 9.17 5.1 37.1 09/14/2015 04:33:15 305 9.17 5.1 37.7 cement in the cellar 09/14/2015 04:33:38 477 9.17 5.1 39.7 09/14/2015 04:34:08 447 9.20 5.1 42.2 09/14/2015 04:34:38 374 9.20 5.1 44.8 09/14/2015 04:35:08 381 9.20 5.1 47.3 09/14/2015 04:35:38 422 9.20 5.1 49.9 09/14/2015 04:36:08 480 9.21 5.1 52.4 09/14/2015 04:36:38 576 9.20 5.1 55.0 09/14/2015 04:37:08 499 9.21 5.1 57.5 09/14/2015 04:37:38 636 9.21 5.1 60.1 09/14/2015 04:38:08 527 9.21 5.1 62.6 09/14/2015 04:38:38 519 9.21 4.7 65.1 09/14/2015 04:39:08 508 9.21 4.1 67.3 09/14/2015 04:39:38 372 9.21 4.2 69.4 09/14/2015 04:40:08 445 9.21 4.1 71.4 09/14/2015 04:40:38 515 9.24 4.1 73.5 09/14/2015 04:41:08 585 9.24 4.1 75.6 09/14/2015 04:41:38 491 9.24 4.1 77.6 09/14/2015 04:42:08 519 9.24 4.1 79.7 09/14/2015 04:42:38 552 9.24 4.1 81.8 Page 6 of 8 • • Well Field lob Start Customer lob Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Time Pressure Density CMT RATE CMT_VOL Message 24-hr PSI LB/G B/M BBL clock 09/14/2015 04:43:38 530 9.25 4.1 85.9 09/14/2015 04:44:08 647 9.25 4.1 87.9 09/14/2015 04:44:38 491 9.26 4.1 90.0 09/14/2015 04:45:08 539 9.26 4.1 92.1 09/14/2015 04:45:38 764 9.27 4.1 94.1 09/14/2015 04:46:08 711 9.26 4.1 96.2 09/14/2015 04:46:38 775 9.26 4.1 98.2 09/14/2015 04:47:38 726 9.26 4.1 102.3 09/14/2015 04:48:08 835 9.27 4.1 104.3 09/14/2015 04:48:38 520 9.27 2.4 106.2 09/14/2015 04:49:08 526 9.27 2.1 107.3 09/14/2015 04:49:38 748 9.27 2.1 108.3 09/14/2015 04:50:08 534 9.28 2.1 109.4 09/14/2015 04:50:38 669 9.27 2.1 110.4 09/14/2015 04:51:08 893 9.27 2.1 111.4 09/14/2015 04:51:38 524 9.27 2.1 112.5 09/14/2015 04:52:08 537 9.28 2.1 113.5 09/14/2015 04:52:38 1252 9.26 0.0 114.4 09/14/2015 04:52:57 1252 9.25 0.0 114.4 112 bbls pumped on displacement 09/14/2015 04:53:08 1251 9.25 0.0 114.4 09/14/2015 04:53:38 1249 9.26 0.0 114.4 09/14/2015 04:54:08 1248 9.26 0.0 114.4 09/14/2015 04:54:38 1248 9.26 0.0 114.4 09/14/2015 04:55:08 1246 9.26 0.0 114.4 09/14/2015 04:55:38 1246 9.26 0.0 114.4 09/14/2015 04:55:44 1247 9.26 0.0 114.4 bleed off pressure/chedcfloats 09/14/2015 04:56:08 1211 9.26 0.0 114.4 09/14/2015 04:56:38 37 9.26 0.0 114.4 09/14/2015 04:57:08 25 9.26 0.0 114.4 09/14/2015 04:57:12 24 9.26 0.0 114.4 .5 bbls retum/floats holding 09/14/2015 04:57:38 20 9.26 0.0 114.4 09/14/2015 04:58:08 21 9.26 0.0 114.4 09/14/2015 04:58:38 21 9.26 0.0 114.4 09/14/2015 04:59:08 20 9.26 0.0 114.4 09/14/2015 04:59:38 19 9.26 0.0 114.4 09/14/2015 05:00:08 19 9.27 0.0 114.4 09/14/2015 05:00:38 20 9.27 0.0 114.4 09/14/2015 05:01:08 82 9.27 0.0 114.4 09/14/2015 05:01:38 53 9.27 0.0 114.4 09/14/2015 05:02:08 20 9.27 0.0 114.4 09/14/2015 05:02:38 15 9.27 0.0 114.4 09/14/2015 05:03:08 15 9.27 0.0 114.4 09/14/2015 05:03:38 14 9.27 0.0 114.4 09/14/2015 05:04:08 14 9.27 0.0 114.4 09/14/2015 05:04:38 15 9.27 0.0 114.4 09/14/2015 05:05:08 15 9.27 0.0 114.4 09/14/2015 05:05:38 15 9.28 0.0 114.4 09/14/2015 05:06:08 15 9.28 0.0 114.4 09/14/2015 05:06:38 15 9.28 0.0 114.4 09/14/2015 05:07:08 14 9.27 0.0 114.4 09/14/2015 05:07:38 15 9.27 0.0 114.4 09/14/2015 05:08:08 14 9.27 0.0 114.4 09/14/2015 05:08:38 15 9.27 0.0 114.4 09/14/2015 05:09:08 15 9.27 0.0 114.4 Page 7 of 8 Well Job Start Customer FI Job Number SRU213-15 SRU213-15 Swanson River Sep/14/2015 Hilcorp C2XM-00138 Date Time Pressure Density CMT RATE CMT VOL Message 24 hr PSI LB/G B/M BBL dock 09/14/2015 05:10:08 14 9.28 0.0 114.4 09/14/2015 05:10:38 14 9.28 0.0 114.4 09/14/2015 05:11:08 14 9.27 0.0 114.4 09/14/2015 05:11:38 15 9.27 0.0 114.4 09/14/2015 05:12:08 16 9.27 0.0 114.4 09/14/2015 05:12:38 15 9.27 0.0 114.4 09/14/2015 05:13:08 15 9.27 0.0 114.4 09/14/2015 05:13:38 15 9.27 0.0 114.4 09/14/2015 05:14:08 16 9.26 0.0 114.4 09/14/2015 05:14:38 15 9.26 0.0 114.4 09/14/2015 05:15:08 15 9.26 0.0 114.4 09/14/2015 05:15:38 15 9.26 0.0 114.4 09/14/2015 05:16:08 14 9.25 0.0 114.4 09/14/2015 05:16:38 15 9.26 0.0 114.4 09/14/2015 05:17:08 15 9.25 0.0 114.4 09/14/2015 05:17:38 16 9.26 0.0 114.4 09/14/2015 05:18:08 15 9.25 0.0 114.4 09/14/2015 05:18:38 15 9.25 0.0 114.4 09/14/2015 05:19:08 15 9.25 0.0 114.4 09/14/2015 05:19:38 15 9.25 0.0 114.4 09/14/2015 05:20:08 15 9.25 0.0 114.4 09/14/2015 05:20:38 17 9.25 0.0 114.4 09/14/2015 05:21:08 15 9.24 0.0 114.4 09/14/2015 05:21:38 16 9.24 0.0 114.4 09/14/2015 05:22:08 16 9.24 0.0 114.4 09/14/2015 05:22:38 16 9.24 0.0 114.4 09/14/2015 05:23:08 15 9.24 0.0 114.4 Post Job Summary Average Pump Rates,bbl/min Volume of Fluid Injected,bbl Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 4.4 5.7 197.0 0.0 35.0 Treating Pressure Summary,psi Breakdown Fluid Maximum Final Average Bump Plug to Breakdown Type Volume Density 4976 17 256 1250 bbl lb/gal Avg.N2 Percent Designed Slurry Volume Displacement Mix Water Temp Cement Circulated to Surface? ❑ Volume bbl % 197.0 bbl 112.0 bbl 80 degF Washed Thru Perfs ❑ To ft Customer or Authorized Representative - Schlumberger Supervisor Circulation Lost ❑ Job Completed x❑ Shane Barber H Kent Griggs - - Page 8 of 8 STATE OF ALASKAa Za Alk KA OIL AND GAS CONSERVATION CO ISSION roIf ra.. REPORT OF SUNDRY WELL OPERATIONS6 ?tilt) 1.Operations Abandon U Plug Perforations pi Fracture Stimulate (� Pull Tubing U , , shutdown LI Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate 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 lorato❑ment Develo 0 Exploratory p ry ❑ 215-100 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20652-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028406 Swanson River Unit(SRU)213-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River/Sterling/Upper Beluga Gas Pool 11.Present Well Condition Summary: Total Depth measured 4,470 feet Plugs measured N/A feet true vertical 4,162 feet Junk measured N/A feet Effective Depth measured 4,383 feet Packer measured 1,981 &4,238 feet true vertical 4,075 feet true vertical 1,807&3,930 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 13-3/8" 120' 120' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.6#/L-80 4,258'MD 3,950'ND Baker Swell Pkr, 1,981'MD 1,807'ND Packers and SSSV(type,measured and true vertical depth) Model D Perm Pkr,N/A 4,238'MD 3,930'ND N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 499 0 0 290 Subsequent to operation: 0 2090 0 0 1060 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 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: 315-743 Contact Joe Kaiser-777-8393 Email jkaiser ac hilcorD.com Printed Name ChadHelelgeson Title Operations Manager Signature ../..41y: Phone 907-777-8405 Date 7/L (o 76 s--3-R. A,1�,,I Form 10-404 Revised 5/2015 RBDMS l,�- MAY p 2 2016 Submit Original Only 1110 r Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 213-15 E-Line 50-133-20652-00 215-100 4/25/16 4/25/16 Daily Operations: 04/25/2016- Monday Obtain PTW. Hold safety meeting. MIRU Halliburton wire line with 7/32" wire. Make up Gamma Ray/CCL, 2 weight bars, A,' and 3.6 GR. Stab on well. Pressure test lubricator 250 psi and 2,500 psi. Open swab and RIH to 4,150'. 286 psi whp. Did not see fluid level. POOH to surface. Isolate well. Bleed down pop off. Make up 20' of 2-7/8" razor charges with 6 spf and 60 degree phasing. Stab on well. PT 250/2,500 psi. Open well, RIH. CCL to top shot 9.5'. Send correlation log into town. Town confirms on depth with Halliburton RMTI log 24 Sep 15. RIH and pick up to 3,968.5' put top shot at 3,978'. Shoot guns for the UB 36-9AX from 3,978'-3,998'. Pressure increased rapidly from 286 psi to 1,178 psi. POOH at 400 fpm. Caught tool string and weight at 3,000'. Lost communication with tool string. Call town to discuss plan forward. 80%safe pull for rope socket is 1,750 lbs. Picked up past 80% limit to 1,900 lbs and started moving up hole. Worked string OOH at 30-40 fpm and pulled heavy at 220'. Believed to be stuck in grease tubes. Close wire line valves. Bleed off lubricator and pop off well. Pulled string and saw some swelling and kinks in line. Fixed line with wire line clamp. Stabbed on well. Equalize valves. Continue to POOH pulling from 1,700 lbs to 2,000 lbs to 174'. Close wire line valves. Pop off well. No wire across tree. Lay down lubricator to check for wire in grease tube. Broke down grease tube and saw rope socket in lubricator. 174' of E-line and tools tring stuck in lubricator. No fish in hole. Broke down lubricator and secured rats nest of e-line. Confirmed all shots fired. SITP dropped to 1,145 psi. Start rigging down Halliburton. Well head secure. Turned well over to pad operator. Continue to RDMO. Wellsite secure. Crews off location. • • Swanson River Field , /4SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 Hilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 1 13-3/8" Conductor- 72#/L-80/Weld 12.347" Surf 120' Driven 7-5/8" Surface 29.7#/L-80/BTC 6.875" _ Surf 2,525' 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' 13-3/8" JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer,1.97"ID 3 4,347' x-nipple,1.875"ID 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 5 4,258' WLEG,1.995"ID U4' ° PERFORATION DETAIL 7-5/s s xr.4 Top Btm Top Btm '1;.. 0, iZone (MD) (MD) (TVD) (TVD) SPF Date Size Status RA Tag d' UB 36-9AX 3,978' 3,998' 3,670' 3,690' 6 4-25-16 2-7/8" Open UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Open 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Open UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Isolated 2,932' i 14t. VA $ 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated .41 1,10 3,333' ilt. tp, Pe ' Y 'No. $7. 3,821' g Al UB 36-9AX w 4,186' im A4P UB38-1 UB 38-4 2 4/5 ;,.01 © UB 38-4 .' UB 38-4 j 4-]/r'4 i ; ' TD=4,470'MD/4,162'TVD PBTD=4,383'MD/4,075'TVD Updated by DMA 04-25-16z • • 215100 II Seth Nolan Hilcorp Alaska, LLC 6 8 7 5 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Hilrtirp Alurka.1.t.c Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED 3 /9/201Ci DATE 03/07/2016 M K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVED DATA TRANSMITTAL MAR 0 8 2015 SRU 213-15 AOGCC Electric log prints and data Prints: Gamma Ray Reservoir Monitor Tool (RMTI) PressureXpress Report CD: 1 Electric logs Li Hilcorp_SRU213-15_18SEP15_XPT_Field_R... 9/24/2015 8:00 AM PDF Document 1;342 KB t7j Hilcorp_SRU213-15_18SEP15_XPT_Test_T... 9/24/2015 8:00 AM Microsoft Excel W... 16 KB a SRU 213-15 RMTI 24-SEP-2015 9/25/2015 12:23 PM PDF Document 1,404 KB SRU_213-15_RMT_24SEP15_main 10/12/2015 9:37 AM LAS File 4,487 KB SRU_213-15_RMT_24SEP15_repeat 10.112/2015 9:37 AM LAS File 472 KB Li SRU_213-15_RMTI_24SEP15 10/12/2015 8:16 AM PDF Document 1;404 KB a SRU_213-15_RMTI_24SEP15_img 10/12/2015 8:16 AM TIFF File 4520 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 907 777.8337 Receive, 7 � � �� 6_,,,,e, Date: V 26765 II Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 nil Aliniokr,[,u: Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 01/20/2016 DATA LOGGED 2,V7/201 CP .,. K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician SiECE' Y E 333 W 7th Ave Ste 100 Anchorage, AK 99501 FEB 022016 DATA TRANSMITTAL AOGCC SRU 213-15 Electric log prints and data Prints: Gamma Ray Reservoir Monitor Tool (RMTI) Gamma Ray Cement Bond Log (CBL) CD: 1 Electric logs a SRU 213-15 RMTI24-SEP-2015 9/25/2015 12:23 PM PDF Dccurnent 1,404 KB 14 SRU_213-15_CBL_24SEP15 10/12/2015 8:16 AM PDF Dccument _._._ 5,968 KB SRU_213-15_CBL_24SEP15_freepipe 10/12/2015 9:31 AM LAS File 357 KB SRU_213-15_CBL_24SEP15_img 10/12/2015 8:16 AM TIFF File 21,412 KB SRU_213-15_CBL_24SEP15_main 10/12/2015 9:30 AM LAS File 6,336 KB SRU_213-15_CBL_24SEP15_repeat 10/1212015 9:32 AM LAS File 367 KB SRU_213-15_RMT_24SEP15_main 10/12/2015 9:37 AM LAS File 4,487 KB SRU_213-15_RMT_24SEP15_repeat 10/12/2015 9:37 AM LAS File 472 KB a SRU_213-15_RMTI_24SEP15 10/12/2015 8:16 AM PDF Document 1,404 KB SRU_213-15_RMTI_24SEP15_img 10/12/2015 8:16 AM TIFF File 4,520 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 907 777.8337 Receivedva 6// }2Date: YY of 7,4 • 40","\l///,/ s THE STATE Alaska Oil and Gas ti -,;-i o fA LAsKA Conservati®n C®rtlrnissi®n _ 333 West Seventh Avenue PI GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433_ OF ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 0, 15- DD 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 213-15 Sundry Number: 315-743 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 '. Foerster Chair DATED this 16 day of December, 2015 Encl. 4\� C 110 0 • RECEIVE STATE OF ALASKA DEC 14 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION i z//b/t 6-- A P P L I CA T I 0 N FOR SUNDRY APPROVALS AOCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations E • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q• Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 215-100 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 7. If perforating: 50-133-20652-00 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.716 • Will planned perforations require a spacing exception? Yes ❑ No [-1Swanson River Unit(SRU)213 15 9. Property Designation(Lease Number): 10. Field/Pool(s): A028406 ' Swanson River/Sterling/Upper Beluga Gas Pool • 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): 4,470' ' 4,162' " 4,383' 4,075' 1,243 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 13-3/8" 120' 102' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790p si Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-3/8" 4.6#/L-80 4,258 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Swell Pkr;Model D Perm Pkr;N/A 1,981'MD/1,807'TVD;4,238'MD/3,930'TVD;/N/A 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: January 1,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS E . WAG ❑ GSTOR ❑ SPLUG El 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 ('�' l`'�If Phone 907-777-8405 Date 1 /y COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. -, ►5 - 7y3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RB') 't Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 4 Subsequent Form Required: /6 - /O'( � APPROVED BY Approved by: iii COMMISSIONER THE COMMISSION Date: 2.--/6 —/S ®,° `� J�' I� �Z 's`ed �' ��'l�✓'� Submit Form and Form 10-403 Revised 11/2015 r I o alid for months from the date of approval. Attachments in Duplicate tL•ii°►j • • 111 Well Prognosis Niko,,,.Ua4a.LI. Well: SRU 213-15 Date: 12/11/2015 Well Name: SRU 213-15 API Number: 50-133-20652-00 Current Status: Active Gas Well Leg: N/A Estimated Start Date: January 1st, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-100 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: 1,138 psi @ 3,770' TVD (Based on Flowing PT Surveyl0/24/2015) Maximum Expected BHP: 1,635 psi (Based on RFT Tool 9/17/2015) Max. Predicted Surface Pressure: 1,243 psi (Based on actual reservoir conditions and gas gradient to surface(0.10psi/ft)) Brief Well Summary SRU 213-15 was drilled as a Grass roots monobore completion in 2015 to target gas sands in the Sterling/Upper Beluga formations. In October 2015, 2 zones were perforated in 4 different sands. The well began to make water, so a packer with a ceramic disk were installed.The well currrently produces 2.4 MMscfd and 5 bbl of. water. The purpose of this work/sundry is to add perforations in the Sterling/Upper Beluga formation. Notes Regarding Wellbore Condition • Plan to tag/drift with slickline before running E-line. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 1. RU 2-7/8"6 spf wireline guns. 2. RIH and perforate the following intervals and test zones individually: Zone Sands Top (MD) Btm (MD) FT SPF Sterling/Upper Beluga 36-9 4,100 4,140 40 6 Sterling/Upper Beluga 36-9X 4,060 4,080 20 6 Sterling/Upper Beluga 36-9A 4,040 4,060 20 6 Sterling/Upper Beluga 36-9A 4,000 4,015 15 6 Sterling/Upper Beluga 36-9AX 3,978 3,998 20 6 Sterling/Upper Beluga 36-9A2 3,926 3,930 4 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using Coorelation Log. d. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. e. Install Crystal gauges. Record tubing pressures before and after each perforating run. • • 11 Well Prognosis Ililvorp 11;o-6n.1.1. Well: SRU 213-15 Date: 12/11/2015 f. All perforations in table above are located in the Sterling/Upper Beluga Pool based on Conservation Order No. 716. 3. RD E-line. 4. Turn well over to production. E-line Procedure(Contingency): 5. If any zone produces sand and/or water. 6. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. a. SITP will be+/- 1,200 psi (remaining gas). 7. RIH and set 4-1/2" CIBP at depth above zone. Or 8. RIH and set 4-1/2"Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • Swanson River Field ini SCHEMATIC Well: SRU 213-15 API #: 50-133-20652-00 Hilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor- 68#/J-55/Weld 12.415" Surf 120' Driven 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,521' 4-1/2" Production 12.68/L-80/DWC/C HT 3.918" Surf 4,466' 13-3/8 2-3/8" Tubing 4.6#/L-80 EUE 1.995" 4,239' 4,258' JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer 2 4,238' Model D Perm Packer,1.97"ID 3 4,347' x-nipple,1.875"ID 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 5 4,258' WLEG,1.995"ID PERFORATION DETAIL 7-5/8" '4 Top Btm Top Btm Zone SPF Date Size Status (MD) (MD) (TVD) (TVD) RATag UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Perforated 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Perforated UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Isolated w/ plug 2' 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated w/ Plug 3,333' C tt4 V o 3,821' UB 38-1 4,186' Q UB 38-4 2 3 r44, ---r•4/5 UB38-4 -• UB 38-4 4-1/2" a '6-• TD=4,470'MD/4,162'TVD PBTD=4,383'MD/4,075'TVD Updated by CJD 11-05-15 PROPOSED Swanson River Field Well: SRU 213-15 SCHEMATIC API #: 50-133-20652-00 Hilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' p., CASING DETAIL +, Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor- .,:.eel 72#/L-80/Weld 12.347" Surf 120' Driven ! �F 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' r 13-3/8"1,t 4, 1t4," va f, , JEWELRY DETAIL I `o' No Depth Item 1 1,981' Baker Swell Packer tf' 2 4,238' Model D Perm Packer,1.97"ID yr , i Wit. 3 4,347' x-nipple,1.875"ID 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID 5 4,258' WLEG,1.995"ID �nk, � 1 err v ,i.e i l0 ,I , 'tie . 9 PERFORATION DETAIL 7-5/8Zone Top Btm Top Btm 0- , (MD) (MD) (TVD) (TVD) SPF Date Size Status RATag j a UB 36-9A2 ±3,926' ±3,930' ±3,618' ±3,622' 6 TBD 2-7/8" Proposed depths: UB 36-9AX ±3,978' ±3,998' ±3,670' ±3,690' 6 TBD 2-7/8" Proposed ±4,000' ±4,015' ±3,692' ±3,707' 6 TBD 2-7/8" Proposed y 9 'r",t UB 36-9A 2937 A t7; ±4,040' ±4,060' ±3,732' ±3,752' 6 TBD 2-7/8" Proposed ti UB 36-9X ±4,060' ±4,080' ±3,752' ±3,772' 6 TBD 2-7/8" Proposed 'H UB 36-9 ±4,100' ±4,140' ±3,792' ±3,832' 6 TBD 2-7/8" Proposed 0 ko..,0 v UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Perforated 3,333 *' 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Perforated g UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" Perforated 13 r 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Perforated a 3,821' UB 36-9A2 ,; UB 36-9AX UB 36-9A UB 36-9X , UB 36-9 4,185 U838-1 UB 38-4 2 y,yy. L S I. � 4/5 1 UB 38 4` a UB 38-4 J 4uz" xtr TD=4,470'MD/4,162'ND PBTD=4,383'MD/4,075'ND Updated by JEK 12-11-15 • 2\S- 100 Seth Nolan Hilcorp Alaska, LLC GeoTech 3i' 3 Centerpoint Drive, Suite 1005�� Anchorage, AK 99503 Tele: 907 777-8308 Hilaiarr:Uasku,1.1 I Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/25/2015 To: Alaska Oil & Gas Conservation Commission _ �--IVtevc��G► CTu1•� �� 333 W 7th Ave Ste 100~ np�' �U Anchorage, AK 99501 SAMPLE TRANSMITTAL RECEIVED DEC 092015 SRU 213-15 Washed and Dried Samples: 3 Boxes AOGCC Transmitted herewith are cuttings from SRU 213-15 WELL SAMPLE INTERVAL SRU 213-15 2520' — 3200' SRU 213-15 3200' — 3900' SRU 213-15 3900' —4470' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received W 0 , Date: RECEIVED ....70 DEC j i. ZU15 AOGCC • 215100 11 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 DATA LOGGED Hilrnrr Abeam.1.1 I Fax: 907 777-8510 t2/7.12015 E-mail: snolan@hilcorp.com M.K.BENDER DATE 11/23/2015 ifiSiCE p Novvet) To: Alaska Oil & Gas Conservation Commission 2 •2015 Makana Bender AQGe Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SRU 213-15 Electric log and Mudlog prints and data Prints: ROP-DGR-EWR-ALD-CTN 2"/5" MD, DGR-EWR-ALD-CTN 2"/5"TVD, XBAT-DGR-EWR-ALD-CTN 2"/5" MD, XBAT-DGR-EWR-ALD-CTN 2"/5"TVD, DGR-ALD-XCAL 5" MD Formation Log 5" MD/TVD, Formation Log 2" MD/TVD, LWD Combo Log 2" MD/TVD, Gas Ratio Log 2" MD/TVD, Drilling Dynamics 2" MD/TVD CD: 1 Electric logs 2 6 4 9 9 CGM 1111212015 11:10 File folder vA Definitive Survey 11,12.1201511:11 ... File folder • DLIS+L.AS 11112/2015 11:11 File folder EMF 11,12/2015 11:11 ,., File folder , PDF 11/12/201511:12... File folder TIFF 11/12/201511:12... File folder CD: 2 Mudlogs 2 6 4 9 8 Daily Reports 10/19/2015 3:43 PM File folder DML Data 10119/2015 3:43 PM File folder obi Final Well Report 1©119/20153:13 PM File folder LAS Data 10/19/2015 3:43 PM File folder i Log PDFs 10/19/2015 3:43 PM File folder • Log TIFFs 1011912015 3:43 PM File folder Show Reports 10/1912015 3:43 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 8 ✓d� � Date: • • • ECE STATE OF ALASKA NOV 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑✓ - SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 2OAAC 25.105 20AAC 25.110 Development [ . Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No.of Completions: 1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: '10/22/2015 - `215-100/315-591. 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 'September 11,2015 . 50-133-20652-00-00 - 4a. Location of Well(Governmental Section): PAN Mt, 8. Date TD Reachled: 16.Well Name and Number: Surface: • 2158'FNL, 1041'FWL,Sec 15,T8NYSM,AK • September yr,.2015 'SRU 213-15 Top of Productive Interval: 9. Ref Elevations: KB: 335'• 17. Field/Pool(s): Swanson River Field 2398'FSL, 51'FWL, Sec 15,T8N, R9W,SM,AK GL:317' - BF: 317' . Sterling/Upper Beluga Gas Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2392'FSL,51'FWL, Sec 15,T8N, R9W,SM,AK • 4,238'MD/3,929'TVD A028406 - 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 348893 • y- 2480102' Zone- 4 - 4,470'MD/4,162'TVD. N/A TPI: x- 347892 y- 2479397 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 347891 y- 2479391 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes [(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary ROP-DGR-EWR-ALD-CTN 2"/5"MD, DGR-EWR-ALD-CTN 2"/5"TVD, Formation Log 2"/5"MD/TVD, LWD Combo 2"MD/TVD,Gas Ratio 2"MD/TVD, Drilling Dynamics 2"MD/TVD PM.- l ( /"�t. '- 23. / CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADEHOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM Y2,r,r PULLED 13-3/8" 68# J-55 Surface 120' Surface 120' Driven Driven ✓ i 7-5/8" 29.7# L-80 Surface 2,521' Surface 2,261' 9-7/8" L-157 bbls 12#/T-43 bbls 15.4# 94 bbls 4-1/2" 12.6# L-80 Surface 4,466' Surface 4,157' 6-3/4" L-51.6 bbls 13.5#/T-38 bbls 15.3# 0 bbls 24.Open to production or injection? Yes [ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4-1/2" 4,466' 1,981'MD/1,807'TVD 1.4,145'-4,155'MD/3,837'-3,847'TVD 2.4,218'-4,223'MD/3,910'-3,915'TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Model D Perm Packer @ 4,238'w/10k Dual Ceramic Disc Was hydraulic fracturing used during completion? Yes❑ No F • 3. 4,246'-4,256'MD/3,938'-3,948'TVD(isolated w/plug) 4. 4,336'-4,341'MD/4,028'-4,033'TVD(isolated w/plug) Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 10/5/2015 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 10/26/2015 24 Test Period .. .0-0 1956 0 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 720 0 24-Hour Rate . 0 1956 - 0 N/A Y-�"i RBD NOV 12 2015 Form 10-407 Revised 11/2015CONTINUED ON PAGE 2 Submit ORIGINIAL NIAL o , 41 C- -% dr 28.CORE.DATA Conventional Os): Yes ❑ No ❑ Sidewall Corees ❑ No ❑✓ • If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑., Permafrost-Top N/A N/A If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base N/A N/A Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 4,145' 3,837' information, including reports, per 20 AAC 25.071. ST A7 2,665' 2,386' ST A9 2,815' 2,522' ST Al 1 3,058' 2,753' ST B2 3,251' 2,943' ST B4 3,443' 3,134' ST B5ST 3,518' 3,209' ST B7SB 3,898' 3,590' Beluga 3,959' 3,651' UB 36-9AST 3,964' 3,656' UB 36-9ST 4,063' 3,755' UB 38-0ST 4,124' 3,816' UB 38-1ST 4,143' 3,835' UB 38-4ST 4,162' 3,853' UB 38-4SB 4,298' 3,989' Formation at total depth: Beluga 31. List of Attachments: Wellbore Schematic, Days vs Depth, MW vs Depth, Daily Drilling and Completion Reports,Casing and Cementing Reports, Definitive Directional Surveys. Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email: mmyersCa7hilcorp.com Printed Name: Monty Myers Title: Drilling Engineer Signature:J. Phone: 907-777-8431 Date: if• 9 - Z o 1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to:core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only Swanson River Field Well: SRU 213-15 . API #: 50-133-20652-00 Hilcora Alaska,LLC PTD: 215-100 RKB:MSL=18.90' APC CASING DETAIL yt< NF Size Type Wt/Grade/Conn ID Top Btm ",*i 41,r Conductor- s+/ +" 13 3/8" 68#/J-55/Weld 12.415" Surf 120' y -,4 Driven � ,,t, ',r*- ' 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,521' F 4-1/2" Production 12.64/L-80/DWC/C HT 3.918" Surf 4,466' 41 4` / 2-3/8" Tubing 4.6#/L-80 EUE 1.995" 4,239' 4,258' 13-3/8'4: 1. tf? ti v $ y 4,14 41 ,x. JEWELRY DETAIL is,, t l 0,01 ';) „'41 r. No Depth Item wf 'v,4• i '' i 1 1,981' Baker Swell Packer '> 2 4,238' Model D Perm Packer,1.97"ID 4 `%ft--, 4,347' x-nipple,1.875"ID ' +a4� ' 4 4,256' 10K Dual Ceramic Disc,(intact),1.995 ID , t ,: >4 « 5 4,258' WLEG,1.995"ID iik iii > f 1 l r'�` PERFORATION DETAIL 7-5/8' '' " Zone Top Btm Top Btm SPF Date Size Status t ''.X (MD) (MD) (TVD) (TVD) RA Tag J'. UB 38-1 4,145' 4,155' 3,837' 3,847' 6 10-2-15 2-7/8" Perforated i4-' 4,218' 4,223' 3,910' 3,915' 6 10-2-15 2-7/8" Perforated .w ,' Isolated w/ y;� n UB 38-4 4,246' 4,256' 3,938' 3,948' 6 10-2-15 2-7/8" plug 2,932 a r 4,336' 4,341' 4,028' 4,033' 6 10-2-15 2-7/8" Isolated w/ N,,! 3,333' li 4 olt i. 'J ,s 3,821' ( ii.1'.., V r k'd e rt tr 1 T!9 1' UB38-1 4,185 UB 38-4 r 2 3 -$4/5 UB 38-4 UB 38-4 ti TD=4,470'IsD/4,162'TVD PBTD=4,383'MD/4,075'TVD Updated by CJD 11-05-15 Hilcorp Energy Company Composite Report Well Name: SRF SRU 213-15 Field: Swanson River Field County/State: ,Alaska )(LAT/LONG): svation(RKB): 18 API#: Spud Date: 9/11/2015 Job Name: 1511440D SRU 213-15 DRILLING Contractor AFE#: 1511440D AFE$: Activity Date Ops Summary 9/6/2015 Prep rig for rig move.Cont to prep to lower pit roofs.Get boiler, pumps, mud pits and out buildings ready for trucks.load out trailers w/assorted equip. Move mud mans house,;Mud loggers house,and Directional drillers house. Rig do drillers doghouse and lower into water tank. 9/7/2015 Cont to prep rig modules for move from KGF to Swanson River,load and ship cement silo's,load and ship service shacks and connex's,RD HandyBerm,tear out and stage doghouse,genset,pits,pumps,;HPU,catwalk. Load exposed rig mats. Hang and tie off Kelly hose,service loop and drill line.Lay over derrick. Clean up exposed felt and liner.Spot cranes. Pick BOP stack from cellar area. Pick;derrick house,pick iron roughneck, LD derrick windwalls,pick derrick off carrier.;Pick carrier off sub-base and load out on truck,Pick sub off poney subs and load out on a trailer. Load out both poney sub sections,hyd unit,and test pump.PU sub mats.PU liner and felt.;Help truck drivers tie down loads. Fuel equip on location.PU location.;Send crew to Swanson River SRU 213-15 and lay felt,liner,and mats.Had to knock down a berm on the side of the pad and encountered a electric cable.;Called production and they came and checked it out. The cable was an old cable that was out of service and it never got removed.Continue leveling pad for mats. 9/8/2015 Cont to load various items on floats at KGF.Peak on location at 8:00 warming up trucks.At 9:00 Peak transported 2 pit modules,sub-base,pony walls,derrick, pump skid and both cranes to Swanson;River field.Set pony walls over well,spotted cranes,set sub-base,set carrier,set derrick.At 14:30 Peak transported 1 pit module,catwalk,gen 1-2 skid,boiler skid and upright water tank.;Set MP#2, Pits 2,3. Spot HPU in sub. Set combo shack and rig water tank(doghouse). Power up gens.Scope up doghouse. R/U pit mud lines. Raise derrick(not scoped).Hook up svc lines.;Rig is 90%set. 40%rigged up. 9/9/2015 Prepped office trailers for MOB to Swanson,crew raised pit roofs,set centrifuge,hooked up equalizers and suction lines.Office trailers on the road at 09:30 am. Prepped and scoped up derrick,RU;lower torque tube and"T"bar,spotted office trailers,set up comm tower, RU office gen set,took on fuel,staged topdrive on rig floor,spotted mud lab and plugged in,installed ground cables.;Continue rigging up misc service lines. Remove traveling beams in cellar. Dress floor w/ handling tools,work on Saxon corns.Spot and pin gas buster,catwalk(rig is 100%spotted,70%rigged up).;Change out Hi-Cal(double ball valve)and install new saver sub. Build spud mud. Dress shakers. Install DSA set test plug and begin nippling up surface riser(no diverter). 9/10/2015 String Pason cords to offices and service shacks,having trouble linking Pason satellite dish. Install skate on catwalk and function test.Chain off and secure conductor riser. Install ground rods;cables. Inspect and stage DP handling equipment on rig floor. Install 4"valves on conductor.Check torque on deadman. Finish building spud mud.;Troubleshoot communications.Recieve,offload and strap directional tools.Remove plywood from south bridge.;Function mud pumps and swap stroke counter cords. Inspect draw-works driveline couplers.Service draw-works.Replace compensator on topdrive.Set up,rack and tally DP for PU and rack back.;Total Safety installed,calibrated and tested gas detection equipment.Sperry and Canrig set up service shacks.Peak cont to organize yard and stage mud products on mud docks.;Set wear bushing. 12.4735"ID.;Troubleshoot iron roughneck. Control panel not fuctioning equipment. Troubleshoot and repair HPU on top drive. Replace soft start circuit board. R/U spinner hawks and rig tongs to pickup dp.;Replace and repair hydraulic lines for spinner hawks. Function same.;RIH @ Tag btm at 120'MD. Pick up and rack back 30 of 37 stds 4.5"CDS-40, 16.6#drill pipe using spinners due to iron roughneck inoperable. Drift=2.56";Rig accepted at 02:30 hrs on 9-11-15 9/11/2015 Cont to PU rack back a total of 2500'of 4 1/2"DP. Rack and tally HWDP.Clean excessive line tar off crown sheaves.;Held wildlife intervention meeting at Swanson main office with entire rig team and service reps.;PU rack back 16 stands 4 1/2"HWDP in derrick.Flood conductor with no leaks,pressure test mud line at 2500 psi,from mud pumps to topdrive with no leaks.Bled off.;MU directional BHA as follows:7"motor adjusted to 1.5 deg bend,MU varel DT1GJMRS tri- 1 cone bit jetted at 3x18's, 1x16.MU DM collar,float sub and scribe same.RFO=252.61 deg.;MU DGR collar,EWR-P4 collar, PWD, HCIM collar,TM-HOC v� collar,XO and topdrive. Download MWD and shallow pulse test(ok).SLB delivered lead and tail cement to rig.,MU stand HWDP,ease down and spud well tagging up at 120'. Drill at reduce pump rate and checked for cellar broaching(ok). Rotating:wob 1K,334 gpm-502 psi,40 rpm-7900 ft/lbs on bott torque.;At 130'we lost returns for a minute or so.Then flow steadily climbed back up to our original 37%with no further issues. Eased pump rate up to 367 gpm-640 psi, drilled to 206'.;Pulled up hole from 206'racking back 2 stands HWDP. PU 4 joints 6 3/4"NM Flex DC's.On 4th joint we tagged fill at 188'.;LD joint MU stand HWDP. Drilled ahead from 206'to 234',Rotating:wob 1 to 6K,433 gpm-1010 psi,40 rpm-8600 fUlbs on bott torque.Increased pump rate to 458 gpm-948 psi and worked string twice.;Pulled up hole racking back stand HWDP, PU last joint NM Flex DC and MU stand HWDP.Obtained survey.Service Rep changed radio on comm tower.;Cont drilling from 234'to 390',rotating wob 3 to 4K,459 gpm-992 psi,60 rpm-8000 ft/lbs on bott torque,MW 8.9 ppg/197 vis,ECD's at 9.1.KOP @ 328'.Sliding: 1 to 6K wob,;455 gpm-1009 psi,28 to 38 psi diff, 120 ft/hr ROP.;TOH F/390'-T/271'MD. P/U jars and trip back in to 390'MD. Saw slight overpull @ 320'(10k). Pumped through tight spot and cleaned up with no other issues. Tagged up w/10'fill.;Cont Drlg ahead F/390'-T/639'MD. 460 gpm, 1245 psi on, 1200 psi off,48%flow,60 rpm,8.5k tq on,6.7k tq off,48 max gas,5k wob.;Cont Drlg ahead F/639'-T/1101'MD. 500 gpm, 1538 psi on, 1450 psi off,50%flow,55 rpm,9.2k tq on,7k tq off,69 max gas,5k wob.;Hauled 36 bbls cuttings to KGF G&I for total 36 bbls Hauled 54 bbls Class II junk fluid to KGF G&I for total 54 bbls Hauled 0 bbls cement to KGF G&I for 0 bbls total 9/12/2015 Drill from 1101'to 1196'.Rotating wob000 gpm-1538 psi,55 rpm-9,200 ft/lbs on bott torque,BGunits.;Flow check(static),pulled up hole from 1196'to 206'.Wiped through tight spots at 900',840',715'and 640'.At 594'and 460'had to MU topdrive and backream,496 gpm-40 rpm,then wiped with no;pump or rotation with no problem.;TIH from 206'to 1196'. Had to MU topdrive and wash/ream from 720'to 760',773'to 820',907'to 945'.Wiped each reamed section with no pump or rotation and they were clean.Washed last two stands;to bottom,made connection and started a hi-vis sweep around,drilling ahead once sweep cleared bit.;Cont drilling 9 7/8"hole from 1196'to 1694',rotating wob 4 to 5K,524 gpm-1826 psi,85 rpm-6200 ft/lbs on bott torque,50 to 150 ft/hr ROP, MW 9.1 ppg/vis 220,ECD's at 9.8,BGG 22 to 50 units,;water on at 20 bph.Recieved 7 5/8"casing,racked and tallied same.SLB delivered plug launcher and pump truck.;Cont drilling 9 7/8"hole from 1694'to 1880', wob 5-6K,523 gpm-1930 psi,50%flow,80 rpm-6.2k tq on,5.5k tq off, 50 to 150 ft/hr ROP,MW 9.1 ppg/vis 165,ECD's at 9.75,;1880'pumped a 20 bbl Hi-vis/WALL-NUT sweep-50%increase in cuttings.;Circulate and condition hole @ 1880'MD. Rot and recip pipe,523 gpm, 1815 psi,51%flow,62k up,50k dn w/pumps off. Shut down and monitor well(static).;Wiper trip F/1880'-T/1257'MD then back to bottom. Pulled clean w/slight swabbing last 3 stds. Trip in was clean w/no fill. .5 bbl gain trip out,.8 bbl loss trip in.;Cont drilling 9 7/8"hole from 1880'to 2110', wob 6K,523 gpm-1930 psi,50%flow,80 rpm-6.2k tq on,5.5k tq off, 50 to 150 ft/hr ROP,MW 9.2 ppg/vis 165,ECD's at 9.75.;Cont drilling 9 7/8"hole from 2110'to 2525', wob 7-9K,524 gpm-1956 psi on,45 diff,49%flow,80 rpm,5.6k tq on,6k tq off, 82 ft/hr avg,MW 9.2 ppg/vis 105,ECD's at 9.59,;368k total revs on bit.;Circulate and condition hole. Rot&Recip pipe. 525 gpm, 1920 psi,49%flow,55 rpm,6.2k tq,final ECD's 9.49. Pump 20 bbl hi vis sweep(on time w/no inc in cuttings). 9/13/2015 Pull up hole from 2525'to 206'for wiper trip.Up wt 72K.Pulled to the NM Flex DC's with no issues.Hole took 3.7 bbls over calculated.Monitored well 15 minutes,fluid dropped 4".;TIH on elevators from 206'to 992'and tagged up.Turned string 180 deg and made second attempt with no luck.MU topdrive and washed reamed from 992'to 1010',then wiped spot with no pump;or rotation and was clean.Washed reamed at 474 gpm-1472 psi,40 rpm-6500 ft/lbs off bott �y✓ " torque.;Fill pipe and wash last stand to bottom with no fill.Pumped 20 bbl hi-vis sweep with nutplug around and had no increase in cuttings.Sweep back on t-r ,,i time.417 gpm-1315 psi,75 rpm-6000 nibs torque.;Flow check=static,POOH on elevators from 2525'to 206'(NM flex DC's)with no problem.;LD jars and 1��8 single HWDP,LD XO and 4 NM flex DC's,plugged in and uploaded MWD data.Cont POOH LD remaining BHA,drain and flush motor,Varel tri-cone graded at 1-1.;PU single,MU run tool,retrieve wear ring,LD same.MU stack wash tool,flush hanger profile.PU landing joint,dummy run Cactus hanger(21.45').RU Weatherford casing equipment.RU fillup line.;PJSM,MU shoe track,fill and check floats(ok).Cont PU single in hole with 7 5/8",29.7#,L-80,BTC casing.Top filled on the fly,completely filled every 5 joints.Ran a total of 29 bow springs;centralizers. TIH F/surface to 2490'MD.;@ 2490'MD,M/U circulating swedge and stage pumps up to 231 gpm, 118 psi,23%flow w/no noticeable losses. 8 bbl loss displacement for total csg run. Circ a total of 3700 stks.;Shut down,P/U (\ landing jt w/hanger. M/U same. Land casing w/48k string wt in wellhead. M/U SLB dual drop plug head w/hardlines. P/U clearing wellhead profile and circulate.;Circulate through cmt head @ 223 gpm,230 psi,24%flow. 70k up,54k dn w/pumps @ final set depth of 2520.3'MD. Circulated a total of 4323 stks (1 1/2 total hole volume).;PJSM w/SLB cementers.;SLB pumped 15 bbls water,tested lines at 1200 psi low and 5000 psi high.Tests good.Rig pumped 36 bbls � /1 ' 10 ppg MUDPUSH II at 5.5 bpm-184 psi.;Shut down and lined up SLB pump truck to well.Lined up and dropped bottom plug,SLB mixed and pumped on the fly: '� 157,4 bbls 358sx 12 .•• E -nded Surf-ce Lead cement with 1 ••b cemnet'at 5.5 b.m 450. i. : i-n dr...-. •. . • -... • •,-. ,' . r .• ,- -r 1c,iand 9.1 ppg spud mud at 5 to 4 bpm-400 to 800 psi.At this point we were getting MudPush II to surface and started taking returns to cellar box.;Landed the r'c hanger(was 2'off seat),up wt went from 80K to 70K,down wt went from 60K to 50K.SLB slowed down to 2 bpm-750 psi and bumped the plug 112 bbls into .1J 4; displacement(calculated at 112 bbls);Held 1250 psi for 3 minutes,bled off 1/2 bbl back to truck and floats held.CIP at 04:52 hrs on 9-14-15.Had 36 bbls 5 diji, MudPush to surface.Had+/-94 bbls cement to rface.;RD and released Schlumberger.Mix water temp 75 degrees.Lost no returns throughout the job. Cr Reciprocated string twice per minute up e point we landed,at 8'to 10'per stroke.;R/D SLB cementers. BIO landing jt and make up packoff,Install same as /� ' jel ,,,(A-it.- puri�p�9 7 per Cameron. Begin nipple down of surface riser. 1` • 9/14/2015 LD 7 5/8"landing joint after installing packoff,casing elevators and change out bails(long to short).;RD flow line,ND conductor riser and remove from cellar,ND DSA.Cameron Rep oversaw NU of tubing head.Installed test plug.Cameron Rep tested flange(void)at 500 psi for 5 minutes and;5000 psi for 15 minutes. Good tests.Installed spacer spool.Set 11"BOP stack and MU same.Installed kill and choke lines,drip pan and flow line.Installed koomey lines.BLM Reps Amanda Eagle and;Zach Lyons on location at 15:00 for witness BOP testing.Signed them in and Saxon Safety Rep gave site specific orientation while crew finished NU.Flooded stack lines and choke manifold.:Shell test at 250/3500 psi for 10 minutes each,good tests. Test#1-Annular,Test#2-Upr rams,CM p.i,L / 1,3,4,5,7,Mez kill,dart. Test#3-CM 2,6,8,kill hcr. Test#4-CM 9,11,13,inside kill;Test#5-Choke hcr,man IBOP. Test#6-Inside choke. Test#7-Super U`/ 1 choke. Test#8-Manual choke. Test#9-lwr pipe. Test#10-Blind rams,CM 10,12. Test#11 -TIW replacement.;R/D test equipment. Tested all A"7 components 250 low/3500 high(except annular w/2500 high). 10 min hold on low and high. State waived witness by Jim Regg.;Install wear bushing. Nipple up catch can,bell nipple and install cellar barriers. Prep for BHA. Stage DP. Build 600 bbls 8.9 ppg KCL mud sym ops. 9/15/2015 Level up derrick(low on off side),finish strap DP for PU,secure drip pan,riser and flowline after leveling.;PU MU directional BHA#2 as follows:Varel V513 PDC,5"motor with 1.5 deg bend,float sub,DM,SP4,ALD,CTN,PWD,TM HOC and BAT collars.Plug in and download MWD.RFO=270.17 deg.shallow hole;test(ok)install nukes and p/up flex collars.;Rih f/200't/812'P/up 14 jts of 4-1/2"s-135 dp Rack back 7 std and p/up 52 more jts of 4-1/2"dp t/2400'.;Circ surface to surface.;R/uo and test csg U 3204 psi w/82 gal t/ 3069 psi on chart for 30 min(ok).;Tag top plug @ 2430'MD. Drill shoe track F/2430'-T/2525' MD. Tagged float shoe @ 2515'. 251 gpm, 1353 psi,27%flow,42 rpm,6k tq on,5.5k tq off. 62k rot,68k up,56k dn w/pumps.;Drill new formation F/2525'-T/ 2545'MD/2280'ND. 251 gpm, 1310 psi,26%flow,40 rpm,6k tq on,5.5k tq off,23 max gas.;Displace 9.1 spud mud w/8.85 ppg KCL/Polymer mud. i, 4iDisplace @ 259 gpm, 1035 psi,29%flow,23 rpm,6.4k tq. Circulate until balanced mud wt in/out(8.85 ppg).;Pull up into shoe and R/U to per FIT. Pump @ est t' 1/8 bbl/min.took 7.5 gallons to reach 320 psi. Shut in and monitor. Recorded psi drop F/320 to 160 psi over 30 min. Slow descent.;Chart and record same. Psi increase while pumping showed linear increase w/no indicators of break over. Discussed findings w/Engineer. 11.5 EMW LOT.;Drill 6 3/4"production hole F/2545'-T/ 3105'MD/2799'TVD. 303 gpm, 1340 psi,30 psi diff,31%flow,2-4k wob,60 rpm,5.9k tq on,5.5k tq off. Started drop section @ 2545' MD.;Hauled 0 bbls cuttings to KGF G&I total 236 bbls Hauled 176 bbls Class II fluid to KGF G&I total 1676 bbls Hauled 4 bbls cement to KGF G&I total 98 bbls 1.5'high and 2.2'right of plan @ 3105'MD. 9/16/2015 Continue drlg 6-3/4"dir hole f/3105'U 3352'.;Circ btm up and SPR.;Pull one std Flow chk(ok)pooh(14 std)U 2514'(inside shoe)w/no problems and 3-1/2 bbls over calculated hole fill.flow chk(ok)rih w/no problems No fill and 3 bbls under displacement.;Resume dir drlg 6-3/4"hole f/3352'U 3935'pump 20 bbl high vis sweep while drilling @ 3415'w/50%increase in cuttings. 3710'max gas @ 564 units.;Drill 6 3/4"hole F/3935'-T/4159'MD-3851'ND. 323 gpm, 1685 psi, 120 diff psi,33%flow,3k wob,80 rpm,8k tq on,8.2k tq off,65 bgg.;Rot&Recip pipe circulating hole clean @ 4159'MD. 322 gpm, 1559 psi,33%flow,50 rpm,8.2k tq,70 bgg. Circulated a total of 1.5 btm's up.Monitor well(2 bph static losses).;Wiper trip F/4259'-T/3293'MD. Tripped clean out and in. 4 bbl loss trip out. 1.75 bbl loss trip in. 102k up,72k dn,84k rot(no pumps). Tagged up 2'fill.;Attempted to drill ahead but saw increase in flow and moderate gas breaking out @ surface @ btm's up(only showed 79 units gas). Circulated 2x btm's up with bgg leveling out @ 28 bgg.;Circulated @ 329 gpm, 1730 psi,34% flow,80 rpm,7.9k tq. 8.95 MW. Pumped 20 bbl hi vis sweep(165 vis,9.1 ppg)w/50%increase.;Drill 6 3/4"hole F/4159'-T/4470'MD(TD)-4162'ND. 323• gpm, 1685 psi, 120 diff psi,33%flow,3k wob,80 rpm,8k tq on,8.2k tq off,65 bgg, 10.19 ECD's.TD depth as per Geo.;Circulate and condition hole @ TD (4470'MD). 328 gpm, 1628 psi,32%flow,55 rpm,8.3k tq, 137 bgg. Wt up from 8.95 MW to 9.1 MW due to bgg(reduce bgg F/137 to 8 units).;Monitor well (1.5-2 bph static losses). 110k up,70k dn(pumps off).;TOH F/4470'-T/2917'MD. Pulled clean with no notable issues.;Hauled 70 bbls cuttings KGF G&I total 306 bbls Hauled 360 bbls Class II fluid to KGF G&I total 2036 bbls Hauled 0 bbls cement to KGF G&I total 98 bbls 11.73'@ 178°az from plan(8'high,8'right). it9/17/2015 Continue short trip OOH U 2484'w/nolems and 6.16 bbls over cal.;Monitor well and service rig IIbbl first 30 min then static.;Rih f/2484'U TD @ 4470' w/no problems and had 4'fill and 2.67 bbls ovr Cal.;Rotate and reciprocate pipe circ btm/up w/high gas of 41 units.pump 20 bbls High vis sweep around back on time w/25%increase in cuttings Pump 23 bbl LCM pill @ 10 ppb steal seal 50;and spot it 23 bbls out bit(top pill @ shoe);Pooh to bha with no problems and 5.5 bbls over cal to bha;Work and I/dn bha#2. Remove and secure sources. Download MWD data. L/D smart tools. Drain motor and B/O bit. Bit grade= 1,1,CT,N,X,I,ER,TD. BHA clean.;Service rig;PJSM w/SLB E-line. Spot wireline and R/U same. Make up 3 5/8"RFT tools(31'length). Power up,RIH to 300 perform shallow test(good). RIH and begin logging operations.;Obtain zones of interest logs in priority order. Obtained all high priorities w/28 of 37 targets total w/71 attempts. R/D SLB RFT tools. Monitor well via trip tank(4.79 bbls loss);M/U BHA#3(cleanout assy). RR 6 3/4"PDC w/conventional rotary assy (629.5'length w/HWDP and jars).;Hauled 11 bbls cuttings to KGF G&I total of 317 bbls Hauled 79 bbls Class II fluid to KGF G&I total of 2115 bbls Hauled 0 bbls cement to KGF G&I total of 98 bbls 9/18/2015 Rih w/Bha#3 clean out assy w/no problems U 4470'had 9'fill hole took 1.75 bbls over cal.;Brk circ clean out fill rotate and reciprocate and circ btm/up w/max gas of 91 units.;Lost camp gen-set and Pason and pit bull Rig watch system. Once back on line sent 17 bbl high vis sweep w/flag around back on time w/<10%increase in cuttings.;Pooh sideways w/DP F/4470'MD. Hole took 9.28 bbls.;Clean and prep floor for running 4 1/2"production. Pull wear bushing and flush stack w/stack washer.;Dummy run 4 1/2"hanger w/19.18'RKB.;R/U 100k side doors,double stack power tongs. Size safety clamp and R/U hydraulics. Function ESD's(good).M/U xo to TIW.;PJSM,Inspect float equipment check same(good). Bakerlok shoe track. FS&FC=5.04"OD. Run 4 1/2"DWC, 12.6#,L-80 F/surface-T/1331'MD. Fill on fly,calc disp every 10 its.6200 ft/lb tq.;Circulate 1 1/2 casing volumes @ 1331'MD. 134 gpm, 105 psi.;Continue run 4 1/2"production casing as per detail F/1331'-T/2455'MD w/no issues. Install jewelry(39 cents),marker jts(4)as per detail.;Circulate and condition @ 2455'MD while changing out short bails to long bails. Stage up pumps to 251 gpm,250 psi,22%flow.;M/U swell packer. Continue running 4 1/2"DWC production casing F/2455'-T/3729'MD.;Circulate and condition @ 3729'MD. 238 gpm,285 psi,22%flow.;Continue running 4 1/2"DWC production casing F/ 3729'-T/4445'MD. 7 bbl loss for total casing run.;M/U hanger. R/D weatherford elevators and pull bushings. 54k up,40k dn. S/O and landout hanger on final set depth of 4465'MD w/18k string wt. 9/19/2015 Continue reciprocating pipe while circ in prep for cmt job @ 329 psi @ 234 gpm up/dn wt 60/44k.;Land out w/shoe @ 4465.56'dn pump R/up cmt head, manifold and lines,brk circ thru cmt head @ 340 psi @5 bpm and reciprocated pipe and PJSM w/all on cmt job.;Pump 13 bbls lease water thru all lines and flush same to cutting box.SLB pressured test lines 1400 low and 5200 psi high(good)rig pumped 24.5 bbls of 12.5 ppg mud push,launched btm plug.;SLB mixed and pumped 51.6 bbls of 13.5 ppg Extended lead cmt w/1 ppb cemnet followed by 36 bbls of 15.3 pm conventional tail cmt w/lima cemnet launched top plug.;SLB flush lines w/lease water to cutting box.SLB displaced w/66.0 bbls of 3%KCI brine @ 5 bpm w/FCP @ 1200 psi early U 1700 psi and held for 5 min.;bleed off 1/4 bbl floats held. CIP @ 09:31 hrs.Pipe was reciprocated up to 10 bbls of displacement then landed hanger w/34k. due to increasing up wt w/shoe @ 4465.56'.;Lost 15.3 bbls bbls for complete cmt iob=90.2%returns.EST toc @ 1577'and no mud push noticed in returns.;R/dn cmt equipment and clear floor and set pack off and test U 5000 psi 10 min(ok)set BPV.Haul mud to tank farm.;Nip dn BOPE and associated equipment and prep for rig move.clean pits.;Install dry hole tree. Remove BPV and install TWC,test void U250-5000 psi 30 min each and shell test tree U 250- 5000 psi(ok).Remove TWC. chg/out rear main seal on gen-set#2. l/dn TDS.;R/D service loop and kelly hose. Remove tq tube guide. P/U TDS cradle,UD TDS,hook up TDS to bridle lines. R/D degasser,flush both mud pumps and blowdown mud lines. Cont clean pits.;R/D"T"bar from tq tube,prep derrick for scoping down. Continue cleaning pits. Disconnect mud lines,elect lines,hydraulic lines from derrick. Scope down derrick.;Total Safety rigged down sensors for demob.;Rig released @ 23:59 hrs 9/19/2015 • ! Hilcorp Energy Company Composite Report Well Name: SRF SRU 213-15 Field: Swanson River Field County/State: ,Alaska (LAT/LONG): - svation(RKB): -f t API#: s -� Spud Date: ✓`� Job Name: 1511440C SRU 213-15 COMPLETIONV Contractor X-- C ca AI 1✓ AFE#: 1511440C r V AFE$: C Activity Date Ops Summary 9/24/2015 E-line crew attended rig PTSM and went over SIMOPS.,RU Halliburton E-line, rig pressure tested tree and lubricator repaired leak on wire line valve re-test 250- 2,500 psi(ok)(tree tested to outer wing valves)open well.,RIH#1 w/3.65"gauge ring with no problem and tag @ 4,357'RKB. POOH. RIH#2 w/RMT log tied into LWD log dated Sept 11,2015. Pulling log f/4,368'WLM U swell prk @ 2,000'@ 25 fpm.POOH. RIH#3 w/CBL log f/4,368'WLM U surface with TOC est @ 1,824'and small stringer above. Spotty U 1,983'good solid cmt 2,400'.,RD and secure well. 9/26/2015 Halliburton slick line crew on location. PJSM and go over SIMOPS and RU same for swabing operations.,Pressure tested lubricator 250-2,500 psi(ok).,Swab well with 4-1/2"swab cups starting w/fluid at surface.Swab DN to 1,700'.,Wait on production vac truck to suck out swab tank.Haul off 36.89 bbls.,Continue swabbing until they were not getting any fluid back. Estimated fluid to 3,905'. Recovered a total of 61 bbls back.Tbg should have had a total of 66 bbls.,RD S� wireline equip and equip pulled off location at 2100 hrs. 9/27/2015 Operations pressured up tbg with gas lift gas to 740 psi.,Operations pumped 130 gallons of diesel to pressure up the IA to 2,650 psi to perform a mechanical integrity test. Well bled off to 2,598 psi over a 30 minute test,left diesel on top for freeze protection.,RD pump and equipment,remove from location and bled the IA back to zero psi,operations complete. 10/1/2015 Halliburton arrive on location,PTW,SIMOPS with rig 169.,Spot equipment,RU lubricator,PT to 250-2,500 psi.,Arm 5' 2-7/8"6spf perf gun.,RIH with guns to correlate,send info to town,shoot interval#1 @ 4,341'-4,43A' POOH,200 psi increase in 10 minutes.,Tbg pressure increase to 1,240psi,lay down spent guns all shots fired,bottom 2'of guns wet.,Arm 10'2 7/8"6spf connex perf guns,RIH correlate,bleed 200 psi off well shoot interval#2 @ 4,256-4,246'. POOH. All shots fired gun dry.,Arm 5'2-7/8"6spf connex perf gun,RIH correlate,bleed 200 psi off well shoot interval#3 @ 4,223'-4,218'. POOH,all shots fired bottom,2' of guns wet.,POOH,lay down spent guns,arm 10'2-7/8"6spf connex pert guns.RIH correlate,bleed 200 psi shoot interval 4,156-4,145',fire guns.POOH,all shots fired.,Lay down spent guns,start RDMO location return to shop. 10/10/2015 Schlumberger crew arrive in field @ 0800,PTW,JSA review,drive to location RU equipment,PT 2,500 psi.RIH with PL toolsting,make 6 logging passes 30- 60-90 fpm down logs,tag high @ 4,240' logged top,bottom and above each perforation 3,800'-4,310'.POOH,RDMO. 10/22/2015 Meet at office and mobe to location.PTW and JSA.Rig up lubricator,PT TO 250 psi low and 2,500 psi high.Shut well in.,RIH w/3.75"GR/2-3/4"JB and tie into Halliburton RMTI Log dated 24 Sep 2015 and set down on obstruction at 4,318'.Hit obstruction couple times but didn't make any hole.Was not sticky either. POOH.,RIH w/Tripoint 4-1/2"Model D Permanent Packer Assy and tie into Halliburton RMTI Log dated 24 Sep 2015.Run correlation log and send to town.Get ok to set top packer at 4,238'with element at 4,239'.S•ot sacker and set at 4 238'with 920•si on tubin•. Pick up 30'and go back down and tag packer top at 4,238'.POOH.Everything looked like a good set.,Rig down lubricator and turn well back over to field. ! • Hilcorp Energy Company Swanson River Unit SRF TS 2-15 Pad SRU 213-15 501332065200 501332065200 Sperry Drilling Definitive Survey Report 21 October, 2015 HALLIBURTON Sperry Drilling • Si Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Swanson Riv Unit 213-15 Project: Swanson River Unit TVD Reference: SRU 213-15 @ 335.30usft Site: SRF TS 2-15 Pad MD Reference: SRU 213-15 @ 335.30usft Well: Swanson Riv Unit 213-15 North Reference: True , Wellbore: SRU 213-15 Survey Calculation Method: Minimum Curvature Design: SRU 213-15 Database: Sperry EDM-NORTH US+CANADA Project Swanson River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Well Swanson Riv Unit 213-15 Well Position +N/-S 0.00 usft Northing: 2,480,102.10 usft . Latitude: 60°47'8.688 N +E/-W 0.00 usft Easting: 348,893.10 usft . Longitude: 150°50'44.161 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 317.30 usft Wellbore SRU 213-15 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 9/7/2015 16.58 73.74 55,542 Design SRU 213-15 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 234.01 Survey Program Date 10/8/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 105.32 2,488.57 SRU 213-15 MWD(SRU 213-15) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/14/2015 2,577.49 4,438.14 SRU 213-15 MWD(2)(SRU 213-15) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/16/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -317.30 0.00 0.00 2,480,102.10 348,893.10 0.00 0.00 UNDEFINED 105.32 0.17 170.85 105.32 -229.98 -0.13 0.02 2,480,101.97 348,893.11 0.19 0.06 MWD+SC+sag(1) 170.07 0.19 170.85 170.07 -165.23 -0.33 0.05 2,480,101.77 348,893.14 0.03 0.15 MWD+SC+sag(1) 229.60 0.22 121.04 229.60 -105.70 -0.49 0.17 2,480,101.61 348,893.26 0.29 0.15 MWD+SC+sag(1) 292.47 0.31 136.72 292.47 -42.83 -0.67 0.39 2,480,101.42 348,893.47 0.18 0.08 MWD+SC+sag(1) 359.12 1.13 223.99 359.11 23.81 -1.28 0.05 2,480,100.82 348,893.13 1.74 0.71 MWD+SC+sag(1) 421.42 3.83 234.12 421.35 86.05 -2.94 -2.06 2,480,099.19 348,891.00 4.37 3.39 MWD+SC+sag(1) 482.88 5.44 233.76 482.61 147.31 -5.86 -6.07 2,480,096.31 348,886.95 2.62 8.36 MWD+SC+sag(1) 544.77 8.85 234.88 544.01 208.71 -10.34 -12.33 2,480,091.92 348,880.63 5.51 16.05 MWD+SC+sag(1) 605.75 11.13 235.34 604.06 268.76 -16.38 -21.01 2,480,085.98 348,871.87 3.74 26.63 MWD+SC+sag(1) 667.69 14.40 236.97 664.46 329.16 -23.98 -32.39 2,480,078.53 348,860.40 5.31 40.30 MWD+SC+sag(1) 728.27 16.14 236.72 722.90 387.60 -32.71 -45.75 2,480,069.98 348,846.93 2.87 56.24 MWD+SC+sag(1) 790.92 18.98 235.26 782.62 447.32 -43.30 -61.40 2,480,059.59 348,831.14 4.59 75.12 MWD+SC+sag(1) 10/21/2015 12:22:27AM Page 2 COMPASS 5000.1 Build 73 • III Halliburton Definitive Survey Report Company: Hilcarp Energy Company Local Co-ordinate Reference: Well Swanson Riv Unit 213-15 Project: Swanson River Unit TVD Reference: SRU 213-15 @ 335.30usft Site: SRF TS 2-15 Pad MD Reference: SRU 213-15©335.30usft Well: Swanson Riv Unit 213-15 North Reference: True Wellbore: SRU 213-15 Survey Calculation Method: Minimum Curvature Design: SRU 213-15 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 852.59 20.96 234.35 840.58 505.28 -55.44 -78.61 2,480,047.67 348,813.78 3.25 96.18 MWD+SC+sag(1) 914.79 24.84 233.47 897.87 562.57 -69.71 -98.15 2,480,033.66 348,794.05 6.26 120.38 MWD+SC+sag(1) 976.72 26.50 233.83 953.69 618.39 -85.61 -119.76 2,480,018.04 348,772.24 2.69 147.21 MWD+SC+sag(1) 1,038.07 28.87 233.91 1,008.01 672.71 -102.41 -142.78 2,480,001.53 348,749.01 3.86 175.71 MWD+SC+sag(1) 1,100.26 31.64 232.96 1,061.72 726.42 -121.08 -167.94 2,479,983.19 348,723.61 4.52 207.04 MWD+SC+sag(1) 1,160.65 31.68 233.24 1,113.13 777.83 -140.12 -193.29 2,479,964.48 348,698.02 0.25 238.73 MWD+SC+sag(1) 1,223.63 31.43 233.48 1,166.79 831.49 -159.79 -219.73 2,479,945.15 348,671.32 0.44 271.69 MWD+SC+sag(1) 1,287.09 31.94 233.50 1,220.79 885.49 -179.62 -246.52 2,479,925.67 348,644.28 0.80 305.02 MWD+SC+sag(1) 1,349.38 32.83 234.08 1,273.40 938.10 -199.32 -273.44 2,479,906.31 348,617.11 1.51 338.38 MWD+SC+sag(1) 1,411.43 32.87 234.59 1,325.52 990.22 -218.95 -300.79 2,479,887.04 348,589.51 0.45 372.04 MWD+SC+sag(1) 1,473.12 32.72 234.17 1,377.38 1,042.08 -238.41 -327.95 2,479,867.93 348,562.10 0.44 405.45 MWD+SC+sag(1) 1,534.54 32.35 234.44 1,429.16 1,093.86 -257.68 -354.78 2,479,849.01 348,535.03 0.65 438.48 MWD+SC+sag(1) 1,597.21 31.98 234.92 1,482.21 1,146.91 -276.97 -382.00 2,479,830.07 348,507.56 0.72 471.84 MWD+SC+sag(1) 1,659.02 31.83 235.09 1,534.68 1,199.38 -295.71 -408.76 2,479,811.68 348,480.56 0.28 504.51 MWD+SC+sag(1) 1,721.75 32.34 233.48 1,587.83 1,252.53 -315.16 -435.81 2,479,792.58 348,453.26 1.59 537.82 MWD+SC+sag(1) 1,783.77 32.40 234.29 1,640.22 1,304.92 -334.73 -462.63 2,479,773.36 348,426.19 0.71 571.03 MWD+SC+sag(1) 1,845.60 32.26 233.62 1,692.46 1,357.16 -354.18 -489.37 2,479,754.24 348,399.21 0.62 604.09 MWD+SC+sag(1) 1,907.69 32.32 233.33 1,744.95 1,409.65 -373.93 -516.02 2,479,734.85 348,372.30 0.27 637.26 MWD+SC+sag(1) 1,969.81 32.69 233.54 1,797.34 1,462.04 -393.81 -542.83 2,479,715.31 348,345.23 0.62 670.64 MWD+SC+sag(1) 2,031.36 32.89 233.72 1,849.08 1,513.78 -413.58 -569.67 2,479,695.89 348,318.14 0.36 703.97 MWD+SC+sag(1) 2,093.38 32.90 233.50 1,901.16 1,565.86 -433.56 -596.79 2,479,676.26 348,290.77 0.19 737.65 MWD+SC+sag(1) 2,155.23 33.39 233.71 1,952.94 1,617.64 -453.63 -624.01 2,479,656.55 348,263.29 0.81 771.47 MWD+SC+sag(1) 2,216.90 33.59 233.80 2,004.38 1,669.08 -473.75 -651.46 2,479,636.78 348,235.59 0.33 805.50 MWD+SC+sag(1) 2,277.74 32.63 232.39 2,055.34 1,720.04 -493.70 -678.03 2,479,617.17 348,208.76 2.02 838.73 MWD+SC+sag(1) 2,341.24 32.85 232.43 2,108.75 1,773.45 -514.65 -705.24 2,479,596.58 348,181.28 0.35 873.06 MWD+SC+sag(1) 2,402.93 31.63 231.47 2,160.93 1,825.63 -534.92 -731.16 2,479,576.63 348,155.11 2.14 905.94 MWD+SC+sag(1) 2,465.54 31.93 231.30 2,214.15 1,878.85 -555.50 -756.93 2,479,556.39 348,129.08 0.50 938.88 MWD+SC+sag(1) 2,488.57 32.11 231.19 2,233.68 1,898.38 -563.15 -766.45 2,479,548.87 348,119.46 0.82 951.08 MWD+SC+sag(1) 2,577.49 30.17 236.26 2,309.79 1,974.49 -590.38 -803.45 2,479,522.12 348,082.10 3.67 997.02 MWD+SC+sag(2) 2,639.26 28.62 234.34 2,363.61 2,028.31 -607.62 -828.38 2,479,505.19 348,056.95 2.94 1,027.33 MWD+SC+sag(2) 2,701.14 26.62 236.26 2,418.44 2,083.14 -623.97 -851.96 2,479,489.16 348,033.17 3.54 1,056.00 MWD+SC+sag(2) 2,762.92 23.86 236.41 2,474.31 2,139.01 -638.57 -873.88 2,479,474.84 348,011.06 4.47 1,082.32 MWD+SC+sag(2) 2,825.92 22.22 235.91 2,532.29 2,196.99 -652.30 -894.36 2,479,461.37 347,990.41 2.62 1,106.96 MWD+SC+sag(2) 2,888.05 20.15 235.79 2,590.21 2,254.91 -664.90 -912.94 2,479,449.01 347,971.67 3.33 1,129.40 MWD+SC+sag(2) 2,950.08 17.82 236.02 2,648.87 2,313.57 -676.21 -929.65 2,479,437.92 347,954.81 3.76 1,149.57 MWD+SC+sag(2) 3,012.50 15.65 236.63 2,708.64 2,373.34 -686.18 -944.60 2,479,428.14 347,939.73 3.49 1,167.53 MWD+SC+sag(2) 3,074.02 12.74 238.49 2,768.27 2,432.97 -694.29 -957.32 2,479,420.19 347,926.92 4.79 1,182.58 MWD+SC+sag(2) 3,136.83 10.41 237.78 2,829.80 2,494.50 -700.94 -968.02 2,479,413.68 347,916.12 3.72 1,195.15 MWD+SC+sag(2) 3,196.92 7.86 236.52 2,889.13 2,553.83 -706.10 -976.04 2,479,408.63 347,908.04 4.26 1,204.67 MWD+SC+sag(2) 3,259.70 4.79 227.71 2,951.52 2,616.22 -710.23 -981.57 2,479,404.56 347,902.46 5.11 1,211.57 MWD+SC+sag(2) 10/21/2015 12:22:27AM Page 3 COMPASS 5000.1 Build 73 III i Halliburton , Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Swanson Riv Unit 213-15 Project: Swanson River Unit TVD Reference: SRU 213-15 @ 335.30usft Site: SRF TS 2-15 Pad MD Reference: SRU 213-15 @ 335.30usft Well: Swanson Riv Unit 213-15 North Reference: True Wellbore: SRU 213-15 Survey Calculation Method: Minimum Curvature Design: SRU 213-15 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/700') (ft) Survey Tool Name 3,321.32 2.95 250.78 3,013.00 2,677.70 -712.49 -984.97 2,479,402.36 347,899.03 3.85 1,215.64 MWD+SC+sag(2) 3,382.65 0.90 285.22 3,074.29 2,738.99 -712.88 -986.92 2,479,401.99 347,897.07 3.69 1,217.46 MWD+SC+sag(2) 3,444.89 1.07 334.05 3,136.52 2,801.22 -712.23 -987.65 2,479,402.65 347,896.36 1.33 1,217.66 MWD+SC+sag(2) 3,506.80 1.19 337.02 3,198.42 2,863.12 -711.12 -988.15 2,479,403.77 347,895.87 0.22 1,217.42 MWD+SC+sag(2) 3,570.08 0.72 216.95 3,261.70 2,926.40 -710.83 -988.65 2,479,404.06 347,895.37 2.64 1,217.65 MWD+SC+sag(2) 3,631.91 0.69 206.17 3,323.52 2,988.22 -711.48 -989.04 2,479,403.42 347,894.97 0.22 1,218.35 MWD+SC+sag(2) 3,692.52 0.99 209.85 3,384.13 3,048.83 -712.26 -989.47 2,479,402.64 347,894.54 0.50 1,219.15 MWD+SC+sag(2) 3,756.42 0.75 204.72 3,448.02 3,112.72 -713.12 -989.92 2,479,401.79 347,894.08 0.39 1,220.02 MWD+SC+sag(2) 3,818.47 1.01 195.84 3,510.06 3,174.76 -714.01 -990.24 2,479,400.90 347,893.75 0.47 1,220.80 MWD+SC+sag(2) 3,879.05 0.76 212.04 3,570.63 3,235.33 -714.87 -990.59 2,479,400.05 347,893.38 0.58 1,221.60 MWD+SC+sag(2) 3,942.64 0.62 211.40 3,634.22 3,298.92 -715.52 -991.00 2,479,399.40 347,892.96 0.22 1,222.30 MWD+SC+sag(2) 4,004.57 0.78 192.61 3,696.15 3,360.85 -716.21 -991.26 2,479,398.71 347,892.69 0.45 1,222.93 MWD+SC+sag(2) 4,065.99 0.72 205.25 3,757.56 3,422.26 -716.97 -991.52 2,479,397.96 347,892.42 0.29 1,223.58 MWD+SC+sag(2) 4,126.31 0.98 176.67 3,817.87 3,482.57 -717.83 -991.65 2,479,397.10 347,892.28 0.81 1,224.19 MWD+SC+sag(2) 4,189.32 1.00 184.00 3,880.87 3,545.57 -718.91 -991.66 2,479,396.01 347,892.26 0.20 1,224.84 MWD+SC+sag(2) 4,252.79 0.98 202.73 3,944.33 3,609.03 -719.97 -991.91 2,479,394.97 347,892.00 0.51 1,225.66 MWD+SC+sag(2) 4,314.35 1.06 177.06 4,005.88 3,670.58 -721.02 -992.08 2,479,393.91 347,891.81 0.75 1,226.42 MWD+SC+sag(2) 4,376.33 1.07 181.08 4,067.85 3,732.55 -722.17 -992.06 2,479,392.76 347,891.81 0.12 1,227.08 MWD+SC+sag(2) 4,438.14 1.10 178.24 4,129.65 3,794.35 -723.34 -992.05 2,479,391.59 347,891.81 0.10 1,227.76 MWD+SC+sag(2) 4,470.00 • 1.10 178.24 4,161.51 • 3,826.21 -723.95 -992.04 2,479,390.98 347,891.82 0.00 1,228.10 PROJECTED to TD brian.wheeler@hallib °°„'",,,,r.;, a„Rm,� Checked By: urton.com ':p;�,o,,"" "" °^m^ Approved By: cary.taylor@halliburton.com �,=,e�„xw Date: 10/21/2015 12:22:27AM Page 4 COMPASS 5000.1 Build 73 • • Hi/corp Energy Company CASING&CEMENTING REPORT Lease&Well No. SRU 213-15 Date 13-Sep-15 County Swanson River Unit State Alaska Supv. Rance Pederson/Shane Barber CASING RECORD s � t G-Cr TD 2525.00 Shoe Depth: 2520.92 PBTD: 2435.84 __ Casing(Or Liner)Detail Setting Depths _ No.of Jts. Size Wt. Grade THD Make Length Bottom Top _ SHOE 7 5/8" 29.7 BTC Weatherford 1.63 2,520.92 2,519.29 2 7 5/8" 29.7 L-80 BTC US STEEL 82.07 2,519.29 2,437.22 Float collar 7 5/8" 29.7 BTC _ Weatherford 1.38 2,437.22 2,435.84 36 7 5/8" 29.7 L-80 BTC US STEEL 2,410.19 2,435.84 25.65 Hgr w/pup 7 5/8" 29.7 L-80 BTC _ US STEEL 4.20 25.65 21.45 RKB 7 5/8" 29.7 L-80 BTC US STEEL 21.45 21.45 0.00 Totals Csg Wt.On Hook: 58,000 Type Float Collar. Weatherford No.Hrs to Run: 6 Csg Wt.On Slips: 48,000 Type of Shoe: Weatherford Casing Crew: Weatherford Fluid Description: Spud Mud 9.1 Liner hanger Info(Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure: Centralizer Placement: 29 AT 80' CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 10 Volume pumped(BBLs) 36 Lead Slurry Type: Extended Lead Cement w/1 lb per bbl cemnet Density(ppg) 12 Volume pumped(BBLs) 157 Mixing/Pumping Rate(bpm): 5.5 ` Tall Slurry 2 Type: Conventional , 1 Density(ppg) 154 Volume pumped(BBLs) , Mixing/Pumping Rate(bpm): 5.5 y Post Flush(Spacer) y Type: H2O Density(ppg) 8.3 Rate(bpm): 5 Volume: 10 w LL Displacement: Type: Spud Mud Density(ppg) 9.1 Rate(bpm): 5 Volume(actual/calculated): 112/112 FCP(psi): 750 Pump used for disp: SLB cmtrs Plug Bumped? X Yes No Bump press 1250 Casing Rotated? Yes X No Reciprocated? x Yes No %Returns during job 100 ,Cv Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 36 SPACER,94 CEMENT Cement In Place At: 4:52 Date: 9/14/2015 Estimated TOC: SURFACE Method Used To Determine TOC: VISUAL/Wt/PH test Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tall Slurry w Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): w Post Flush(Spacer) o o Type: Density(ppg) Rate(bpm): Volume: ru Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Post Job Calculations: Calculated Cmt Vol t 0%excess: 96 Total Volume cmt Pumped: 157(lead)+43(tail)=200 bbls Cmt retumed to surface: 94 Calculated cement left in wellbore: 200-94=106 bbls OH volume Calculated: 91.7 OH volume actual: 94.8 Actual%Washout 3 i ! Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. SRU-213-15 Date 19-Sep-15 County Kenai Peninsula Borough State Alaska Supv. Barber/Hauck CASING RECORD TD 4470' Shoe Depth: 4465.56' PBTD: 4383.34' Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length _ Bottom Top Shoe 41/2" 12.68 L-80 BTC WFD 1.62 4,465.56 4,463.94 2 Jnts 4 1/2" 12.68 L-80 BTC 79.19 _ 4,463.94 4,384.75 Flt Clr 41/2" 12.68 L-80 BTC _ WFD 1.41 _ 4,384.75 4,383.34 60 jts 41/2" 12.6# L-80 BTC _ 2,384.14 4,383.34 2,000.61 Swell Pkr 41/2" 12.64 L-80 _ BTC Baker 20.04 _ 2,000.61 1,980.57 50 jts 41/2" 12.68 L-80 BTC 1,958.17 1,980.57 22.40 XO Pup jt 41/2" 12.68 L-80 BTC 2.37 22.40 20.03 Hanger 4.5 x 10.75 _ Cactus 0.85 20.03 19.18 RKB 4 1/2" 19.18 19.18 0.00 Totals 112 its. Csg Wt.On Hook: 49,000 Type Float Collar. Model 402E No.Hrs to Run: 10 Csg W.On Slips: 34,000 Type of Shoe: Bull Nose/303E Casing Crew: WFD Fluid Description: 9.1 ppg 3%KCL polymer,PV 12,YP 21 Liner hanger Info(Make/Model): N/A Liner top Packer?: Yes X No Liner hanger test pressure: 0 Centralizer Placement: 2 on shoe jt 10'f/ea end,1 cent middle bakertok jt, 1 floating cent every jt and odd jts of zones of intrest for(39 total of 6-1/4"X 4.5"Econ-O-Gliders) CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 12.5 Volume pumped(BBLs) 24.5 Lead Slurry Type: EZ Blok Extended Lead Density(ppg) 13.5 Volume pumped(BBLs) 51.6 Mixing/Pumping Rate(bpm): 4.5 Tail Slurry ' Type: EZ Blok Tail Density(ppg) 15.3 Volume pumped(BBLs) 38 Mixing/Pumping Rate(bpm): 4.5 y Post Flush(Spacer) y Type: Density(ppg) Rate(bpm): Volume: w LL Displacement: Type: 3%KCL Brine Density(ppg) 8.4 Rate(bpm): 5 Volume(actual/calculated): 66.7/66.0 044' FCP(psi): 1200 Pump used for disp: SLB Plug Bumped? X Yes No Bump press 1700 r Casing Rotated? Yes X No Reciprocated? x Yes_No %Returns during job 83 j,c,S -7-- Cement Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 9:31 Date: 9/19/2015 Estimated TOC: 1,577 , Method Used To Determine TOC: Volume pumped(BBLs),Return Volumes,and losses along with lift psi. Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry i w Type: lLDensity(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): �✓ m Post Flush(Spacer) gType: Density(ppg) Rate(bpm): Volume: r(4/'''w Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): s /8 w-2 J'L. FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job ll Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: (7"1 iI":. -� Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: WELLHEAD Make Cactus Type Multibowl Serial No. Size 11" W.P. 5k 1�1/ it. Head To 5000 PSIG 10 MIN good OK -('Z?. Remarks: This particular report pertains to the Production Casing and Cement i • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday,April 28, 2016 10:55 AM To: mmyers@hilcorp.com Subject: SRU 215-13 (PTD 215-100) Monty, Looking at this 10-407 also. 1) The surface casing daily report summary doesn't specify that the 43 bbl of tail cement was ever pumped. Can you verify that ? It is listed on the spreadsheet cmt report... 2) CBL and PNL were not listed in Box 22 3) The CBL VDL sucks... maybe should have this rerun for free by Halliburton. Something was wrong with the 5' waveform for most of the log. Amplitude for 3' is ok. 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(Guy.schwartz@alaska.gov). 1 • • SRU 213-15 Days vs Depth 0 SRU 213-15 Actual 500 SRU 213-15 Plan 1000 1500 2000 y 2500 a. ar -a 22 3000 a) 3500 4000 4500 5000 5500 0 2 4 6 8 10 12 14 16 18 Days 10/27/20159:23 AM i i SRU 213-15 MW vs Depth 0 _ SRU 213-15 Plan 1000 - - SRU 213-15 Actual 2000 3000 4000 - - 5000 r ar 6000 aJ IA a) 7000 8000 9000 10000 11000 - — 12000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) ti OF T}I ;1/2- %ji sA THE STATE Alaska Oil and Gas ALAsKA Conservation Commission ka # 333 West Seventh Avenue s TR GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF907.279.1433 ALAS'"Q. MFax: 907.276.7542 www.aogcc.alaska.gov Joe Kaiser Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 213-15 Sundry Number: 315-591 Dear Mr. Kaiser: 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, //r Cathy Foerster Chair 5+ DATED this I day of October, 2015 Encl. 4eo4fs A 1/4,4:_OOiS ?015 • • RECEIVED STATE OF ALASKA SEP 2 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION OT_ /4//// S APPLICATION FOR SUNDRY APPROVALS AOG', (° 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 - Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Initial Perfs 0 • 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 - 215-100 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service [11 6.API Number: Anchorage,AK 99503 50-133-20652-00 - 7. If perforating: , 7� 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 Swanson River Unit(SRU)213-15 Will planned perforations require a spacing exception? Yes ❑ - No 0 �, 9.Property Designation(Lease Number): 10.Field/Pool(s): f Z3 '' A028406 - Swanson River/Sterling/Upper Beluga Gas Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4,470' 4,162' 4,383 4,112 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 120' 13-3/8" 120' 102' Surface 2,525' 7-5/8" 2,525' 2,265' 6,890 psi 4,790 psi Intermediate Production 4,466' 4-1/2" 4,466' 4,158' 8,430 psi 7,500 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Swell Packer;N/A 1,981'MD/1,807'TVD; N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/6/2015 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 ' WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Kaiser Email jkaiser(a�hilcorp.com Printed Name Joe Kaiser Title Operations Engineer Signaturer�� ohne 907-777-8393 Date / '1,.. `: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i5 - 91 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: >;, .. no 05 VAS RBDMS . Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /(,i " y v 7 / �1r 4-1-) APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / �/_/3 ORoIeG,1IiIt4,AL!.d ofsinForm 10-403 Re sed 5/2015 for 12 mon s from the date of approval.74J7/, Attachments in Duplicate • • Well Prognosis Well: SRU 213-15 flacon)AIa k°,LL Date:9/22/2015 Well Name: SRU 213-15 API Number: Current Status: New Grassroots Gas Well Leg: N/A Estimated Start Date: October 6th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-100 First Call Engineer: Joe Kaiser (907) 777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helegson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 0 psi @ 4,165' TVD (No open perforations) Maximum Expected BHP: 1635 psi (Based on RFT Tool) Max. Allowable Surface Pressure: 1218 psi (Based on actual reservoir conditions and gas gradient to surface(0.10psi/ft) Brief Well Summary SRU 213-15 was drilled as a Grass roots monobore completion in 2015 to target gas sands in the Sterling/Upper Beluga formations. The purpose of this work/sundry is to perforate the well for the initial completion in the Sterling formation. Notes Regarding Wellbore Condition • Plan to tag with slickline before running E-line. • Will run Cement Bond Log before swabbing well. • Pressure test IA(4-1/2"x7-5/8")to 2,500 psi before perforating. • Well to be swabbed to TD. • Well pressurized with Gas lift to 700 psi. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 1. RU 2-7/8"6 spf wireline guns. 2. RIH and perforate the following intervals: . Zone Sands _ Top(MD) Btm (MD) FT SPF Upper Beluga 38-4 4,365 4,369 4 6 Upper Beluga 38-4 4,330 4,345 15 6 Upper Beluga 38-4 4,240 4,258 18 6 Upper Beluga 38-4 4,214 4,234 v 20 6 Upper Beluga 36-9 4,104 4,160 56 6 Upper Beluga 36-9 4,128 4,135 7 6 Upper Beluga 36-9 4,106 4,115 9 6 Upper Beluga 36-9X 4,068 4,076 8 6 Upper Beluga 36-9A 4,040 4,062 22 6 --------- ---- Upper Beluga 36-9A 4,000 4,015 15 6 • • Well Prognosis Well: SRU 213-15 llilcoro Alaska,LL Date:9/22/2015 Upper Beluga 36-9AX 3,978 3,998 20 6 Upper Beluga 36-9A2 3,926 3,930 4 6 a. Bleed tubing pressure to 700 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log(pending Tie-in log). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. f. Record tubing pressures before and after each perforating run. g. All perforations in table above are located in the Sterling/Upper Beluga Pool based on Conservation Order No.716. 3. RD E-line. 4. Turn well over to production. E-line Procedure (Contingency): 5. If any zone produces sand and/or water. 6. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. a. SITP will be+/- 1,200 psi (remaining gas). 7. RIH and set 4-1/2"CIBP at depth above zone. Or 8. RIH and set 4-1/2"Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic H . i Swanson River Field . 1mWell: SRU 213-15 SCHEMATIC API #: 50-133-20652-00 Hilcora Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL • Size Type Wt/Grade/Conn ID Top Btm • 13-3/8" Conductor- 72#/L-80/Weld 12.347" Surf 120' Driven 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' 4-1/2" Production 12.68/L-80/DWC/C HT 3.958" Surf 4,466' 13-3/8" i ' JEWELRY DETAIL • No Depth Item 1 1,981' Baker Swell Packer S S► . . 1 7-5/8" A IL RA Tag depths: 2,932' C 3333' C 3,821' C 4,186' a 4-1J2" A 6.: TD=4,470'MD/4,162'1VD PBTD=4,383'MD/4,075'TW Updated by DMA 09-21-15 ` , 0 Swanson River Field PROPOSED SCHEMATIC Well: SRU 213-15 #: 50-133-20652-00 llilcorp Alaska,LLC PTD: 215-100 RKB:MSL=18.90' CASING DETAIL Size Type Wt/Grade/Conn Conductor- ID Top Btm '# +t•:'• 'I. 13-3/8" Driven 72#/L-80/Weld 12.347" Surf 120' #• *i�. 7-5/8" Surface 29.7#/L-80/BTC 6.875" Surf 2,525' as 4-1/2" Production 12.6#/L-80/DWC/C HT 3.958" Surf 4,466' 13-3/s' " JEWELRY DETAIL No Depth Item 1 1,981' Baker Swell Packer `F '< PERFORATION DETAIL 7-5/8" 1 Zone Top Btm Top Btm SPF Date Size Status (MD) (MD) (TVD) (TVD) RA Tag Fi UB 36-9A2 ±3,926 ±3,930 ±3,618 ±3,622 6 TBD 2-7/8" Proposed depths: iff UB 36-9AX ±3,978 ±3,998 ±3,670 ±3,690 6 TBD 2-7/8" Proposed ±4,000 ±4,015 ±3,692 ±3,707 6 TBD 2-7/8" Proposed UB 36-9A 2,937 a ±4,040 ±4,062 ±3,732 ±3,754 6 TBD 2-7/8" Proposed x UB 36-9X ±4,068 ±4,076 ±3,760 ±3,768 6 TBD 2-7/8" Proposed ±4,104 ±4,160 ±3,796 ±3,852 6 TBD 2-7/8" Proposed UB 36-9 ±4,106 ±4,115 ±3,798 ±3,807 6 TBD 2-7/8" Proposed 3333 Q ±4,128 ±4,135 ±3,820 ±3,827 6 TBD 2-7/8" Proposed dx ,2• ±4,214 ±4,234 ±3,906 ±3,926 6 TBD 2-7/8" Proposed ±4,240 ±4,258 ±3,932 ±3,950 6 TBD 2-7/8" Proposed UB 38-4 =a ±4,330 ±4,345 ±4,022 ±4,037 6 TBD 2-7/8" Proposed 140 ±4,365 ±4,369 ±4,057 ±4,061 6 TBD 2-7/8" Proposed 3,821' iii i UB 36-9A2 UB 36-9AX It UB 36-9A 00 4, UB 36-9X } UB 36-9 4,186' i ►0 40 +J, # UB 38-4 M d ho. r IP,, ;,9 ,a1 .1.i 1 41/2'44 witlE grj TD=4,470'MD!4,162'TVD PBT0=4,383'MD/4,075'TVD Updated by DMA 09-21-15 of 71 • wP�� ,�s THE STATE Alaska Oil and Gas 4 'A of Conservation Commission 333 West Seventh Avenue \Tj�'• GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALAS�Q' Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Sterling/Upper Beluga Gas Pool, SRU 213-15 Hilcorp Alaska, LLC Permit No: 215-100 Surface Location: 2158' FNL, 1041' FWL, SEC. 15, T8N, R9W, SM, AK Bottomhole Location: 2401' FSL, 59' FWL, SEC. 15, T8N, R9W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this[ 7day of June, 2015. VO 'N11,1,7 blow ii W STATE OF ALASKA �"Lir A KA OIL AND GAS CONSERVATION COMIb ION JUN 1 1 ?01 PERMIT TO DRILL J3'z I,5 \ 20 AAC 25.005 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone • Q lc.Specify if well is,proposed for: Drill • E Lateral ❑ Stratigraphic Test ❑ Development-Gat.111 Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates El Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: -Blan<et ❑ Single Well ❑ 11.Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244- Swanson River Unit(SRU)213-15 3.Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 5,043' - TVD: 4,739' - Swanson River Unit 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Sterling/Upper Beluga Gas Pool Surface: • 2158'FNL, 1041'FWL,Sec 15,T8N, R9W,SM,AK - A028406 . Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 2450'FSL, 130'FWL,Sec 15,T8N, R9W,SM,AK N/A 7/15/2015 a Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 2401'FSL,59'FWL,Sec 15,T8N,R9W,SM,AK 1720 4,201' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 335.9 feet - 15.Distance to Nearest Well Open Surface: x-348893.18- y- 2480102.04 - Zone-4 GL Elevation above MSL: 317.3 feet. to Same Pool: 1050'to SRU 242-16 16.Deviated wells: Kickoff depth: 300 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) a Maximum Hole Angle: 32 degrees Downhole: 1468 psi i 774 p-- Surface: 1236 psi i 1.'0i Y 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 9-7/8" 7-5/8" 29.7# L-80 BTC 2,500' 0 0 2,500' - 2,248' - Lead-1` ¢A.ft3/Tail-192 ft3 6-3/4" 4-1/2" 12.6# L-80 DWC/C HT 5,043' 0 0 5,043' - 4,739' - 1-:(.-=615 ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plal ❑✓ BOP Sketcr ❑✓ Drilling Program H Time v.Depth Plot Li Shallow Hazard Analyss❑ Diverter SketcY ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requiremens❑✓ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Myers Email mmyers(cr�hilcorp.com Printed Name Monty Myers Title Drilling Engineer Signature ^-N, . Phone8431 Date 6/11/2015 Only Commission Use Only Permit to Drill API Number: _ _ Permit Approval f 1 116 See cover letter for other Number: L/'S-/00 50-/33— µ C_ —'–a_)-LL Date: g requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in sh:RI Other: �° Samples req'd: Ye;❑ I' © Mud log req'd:YEs❑ No® 3506 ig5� 60e ,t st-' .l i H2S measures: Ye;[+j NJ❑ Directional svy req'd:YEs❑ No❑ J� Jts'T�'•' W VZ� �� ~ Spacing exception req'd: YE;❑ M') Inclination-only svy req'd:Ys❑ N Ef Z� /1 2:570 3 5r��i r S- E.c-.'ti-�C v r.L r-r.,i -t= Approved b0 APPROVED 6/ 1 t) IS y:�` COMMISSIONER THE COMMISSION ION Date: OiReI �A Submit Formand Form 10-40 evised 10/2012) a I o onths from the date of approval(20 AAC 25.005(8) Attachments in Duplicate Monty Myers Hilcorp Alaska, LLC Drilling Engineer • P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Ilileorp Ala,ka, June 11th, 2015 RECENED Commissioner Alaska Oil &Gas Conservation Commission JU V 11 2W3 333 W. 7th Avenue Anchorage, Alaska 99501 AOGCC Re: SRU 213-15 Dear Commissioner, Enclosed for review and approval is the Permit to Drill for SRU 213-15 gas well. SRU 213-15 is an S-shaped directional grassroots development well to be drilled off of the SRU 32-15 pad. Subsurface modeling and seismic interpretation, along with production data, indicates that there is remaining gas reserves stranded in the Sterling and Upper Beluga sands. This well will be targeting PUD reserves in the Sterling sands. These existing reserves are not recoverable in existing wellbores due to lack of take points or mechanical condition of other existing wellbores. Drilling operations are expected to commence approximately July 15th, 2015. • The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, • Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • Hileorp Alaska, LLC SRU 213-15 Drilling Program Swanson River Field Version 0 May 29th, 2015 • S SRU 213-15 Hilcorp Drilling Procedure Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program- 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 N/U 13-3/8"Conductor Riser 12 11.0 Drill 9-7/8"Hole Section 14 12.0 Run 7-5/8"Surface Casing 18 13.0 Cement 7-5/8"Surface Casing 20 14.0 BOP N/U and Test. 23 15.0 Drill 6-3/4"Hole Section 24 16.0 Run 4-1/2"Production Casing 29 17.0 Cement 4-1/2"Production Casing 32 18.0 RDMO 35 19.0 BOP Schematic 36 20.0 Wellhead Schematic 37 21.0 Days Vs Depth 38 22.0 Geo-Prog 39 23.0 Anticipated Drilling Hazards 40 24.0 Saxon Rig 169 Layout 42 25.0 FIT Procedure 43 26.0 Choke Manifold Schematic 44 27.0 Casing Design Information 45 28.0 6-3/4"Hole Section MASP 46 29.0 Spider Plot(NAD 27)(Governmental Sections) 47 30.0 Surface Plat(As Staked)(NAD 27) 48 31.0 Surface Plat(As Staked)(NAD 83) 49 • I SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 1.0 Well Summary Well SRU 213-15 Pad&Old Well Designation SRU 213-15 is a grass roots well on SRU Pad 32-15 Planned Completion Type 4-1/2"Production tubing Target Reservoir(s) Sterling/Upper Beluga • Planned Well TD,MD/TVD 5,043 MD/4,739' TVD PBTD,MD/TVD 4,963' MD/4,658' TVD Surface Location(Governmental) 2158' FNL, 1041' FWL, Sec 15,T8N,R9W, SM,AK Surface Location(NAD 27) X=348893.186, Y=2480102.042 Surface Location(NAD 83) X=1488916.543,Y=2479863.861 Top of Productive Horizon (Governmental) 2450' FSL, 130' FWL, Sec 15,T8N,R9W,SM,AK TPH Location(NAD 27) X=347972.01, Y=2479448.15 TPH Location(NAD 83) X=1487995.328,Y=2479209.982 BHL(Governmental) 2401' FSL, 59' FWL, Sec 15,T8N,R9W, SM,AK BELL(NAD 27) X=347900,Y=2479400 BHL(NAD 83) X=1487923.315,Y=2479161.934 AFE Number 1511440D AFE Drilling Days 5 MOB, 17 DRLG AFE Completion Days AFE Drilling Amount $2,982,140 AFE Completion Amount $600,000 Maximum Anticipated Pressure (Surface) 1236 psi(Drilling) ✓ Maximum Anticipated Pressure (Downhole/Reservoir) 1468 psi Work String 4-1/2" 16.6#S-135 CDS-40(Saxon Owned String) RKB—GL 335.9'(317.3 + 18.6) Ground Elevation 317.3' BOP Equipment 11"5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Version 0 June,2015 • S SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska_ LLC Hilcorp EwellPal Changes to Approved Permit to Drill Date: 6-1-2015 Subject: Changes to Approved Permit to Drill for SRU 213-15 File#: SRU 213-15 Drilling Program Any modifications to SRU 213-15 Drilling Program will be documented and approved below. Changes to an approved APD will be approved in advance by the AOGCC and BLM Sec Page Date Procedure Change Approved Approved By By Approval Drilling Manager Date Prepared Drilling Engineer Date Page 3 Version 0 June,2015 • I SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole OD(in) ID(in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD(in) (#/ft) (psi) (psi) (k-lbs) Cond 13-3/8" 12.415" 12.259" 14.375" 68 J-55 Weld 3450 1950 - 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 575 6-3/4" 4-1/2" 3.918" 3.833" 5.0" 12.6 L-80 DWC/C HT 8430 7500 288 4.0 Drill Pipe Information: Hole OD(in) ID(in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 June,2015 SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com..mmyers@hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3)individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston:0: (907)777-6726 C: (907)227-3189 b. Mark Tornai:0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0:(907)777-8317 C: (907)602-5178 2. Spills:Julieanna Orczewska: 0:907-777-8444 C:907-715-7060 • Notify Drlg Manager 1. Paul Mazzolini:0:907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com Page 5 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 6.0 Planned Wellbore Schematic Swenson River Unit PROPOSED ROPOSED SRU#213-15 PTD: 000.000 API: 50-000-00000-00 if.k.r�,tlk..t x.11 i JJ CASING DE-4IL 13-318" 4 Size ''pe Wt Grade Btn Conductor 13-3/8" —Driver 68 J-55 Vdelo 12.415" Surf 120' to Set Depth 7-5/8" Surf Csg 29.7 L-80 BTC 6.875" Surf 2,503' 8.8 pp; 4-1/2' Prod Csg 12.6 L-80 p''FC.lC 3.918" Surf 5.043' 13.0 poi 7.5;8- 1 M�- Drillirg Info L ' Hole Senior Casir8 P:'�JJ Warkstrir�g p 9-7/8" 7-5/8" 8.8 ppg 4-1/2" I - 1 r 6-3/4" 4-1/2" 9.5-10.5 ppg 4-1/2" JEWELRY DETAIL I No. Depth ID CD Item 1 2,000' 3.918" 6.875" Baker Swell Packer 6-3/4" • Hole Mi • ji PBTD=190' PBTS'D=x,659' 7.0 TD=5.013` TVD=4,739' Page 6 Version 0 June, 2015 • • titSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary SRU 213-15 is an S-shaped directional grassroots development well to be drilled off of the SRU 32-15 pad. Subsurface modeling and seismic interpretation,along with production data, indicates that there is remaining gas reserves stranded in the Sterling and Upper Beluga sands.This well will be targeting PUD reserves in the Sterling sands.These existing reserves are not recoverable in existing wellbores due to lack of take points or mechanical condition of other existing wellbores. Drilling operations are expected to commence approximately July 15th,2015. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 2,500 MD/ 2,248' TVD and cemented to surface to ensure protection of any shallow freshwater resources. No freshwater aquifers appear below 1700' in the Swanson River Unit as per • 40 CFR 147.102(b) (1) (i). Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste &mud generated during drilling and completion operations will be hauled to the Kenai Gas Field • G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: • 1. MOB Saxon Rig# 169 to well site 2. N/U conductor riser. (No diverter, diverter waiver requested) 3. Drill 9-7/8"hole to 2500' MD. Run and cmt 7-5/8" surface casing. 4. ND conductor riser, N/U &test 11"x 5M T3-Energy BOP. 5. Drill 6-3/4"hole section to 5,034' MD. Perform Wiper trip. 6. Perform RFT logging 7. POOH laying down drill pipe. 8. Run and cmt 4-1/2"production casing . 9. N/D BOP, N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole:GR+Res LWD. 2. Production Hole:GR+Res+Den/Neu LWD. • 3. Mud loggers from surface casing point to TD. • Page 7 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling of SRU 213-15. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. BLM requires 48 hrs notice prior to testing. • The initial test of BOP equipment will be to 250/3500 psi& subsequent tests of the BOP equipment will be to 250/3500 psi for 10/10 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure both AOGCC approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: • Diverter waiver requested due to the recent drilling of SRU 32C-15 on a nearby pad. No issues were experienced while drilling the surface hole. Surface casing for SRU 32C-15 was set at 3000' TVD. Surface casing is requested to be set at 2,248' TVD on SRU 213-15.No shallow hydrocarbon zones will be penetrated. fL O. • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. 1V o Hilcorp requests approval to install a 3-1/8" 5M HCR valve on kill line in lieu of a check valve. Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. Page 8 Version 0 June,2015 S SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 9-7/8" • No diverter utilized n/a • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 6-3/4" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running&cement operations. • Any other notifications required in APD. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, &testing • Any other notifications required in APD. Additional requirements may be stipulated on APD and Sundry. Page 9 Version 0 June,2015 • • 11 SRU 213-15 Drilling Procedure Rev 0 Hilcorp EmogY ComPanY Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email: jim.regg@,alaska.gov Guy Schwartz/Petroleum Engineer/(0):907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0):907-793-1247/Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone:907-793-1236(During normal Business Hours) Notification/Emergency Phone:907-659-2714(Outside normal Business Hours) BLM Mutasim Elganzoory/BLM Petroleum Engineer/(0): 907-271-3406 (C):907-717-4039 Email:melganzoory@blm.gov Use the below email address for BOP notifications to the BLM: BLM_AK AKSO EnergySection_Notifications@blm.gov Page 10 Version 0 June,2015 I SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 13-3/8"conductor at+/-120' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M"A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot&R/U company man &toolpusher offices. 9.7 Mud loggers not required on surface hole section. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 9-7/8"hole section. 9.10 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi(85%) /333 gpm(100%) with 5-1/2" liners. Page 11 Version 0 June, 2015 • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 10.0 N/U 13-3/8" Conductor Riser 10.1 N/U 13-3/8"Conductor Riser • Ensure line does not direct flow from trip tank straight down the flowline. Fill up line and flowline should be oriented 90 degrees to each other at approx.the same height. • Ensure flowline outlet installed so that enough slope exists to carry cuttings to the shakers. • Consider adding additional drainage points at the bottom of the conductor riser if deemed necessary. • R/U fill up line to conductor riser. 10.2 Set wearbushing in wellhead. Page 12 Version 0 June, 2015 . HSRU 213-15 Drilling Procedure Rev 0 - p -cr 10.3 Ri: Orientation on SRU 32-15 pad: ' . , . «� . y iiiiii 1 f . , i .. . . au__ { ilr - 'dfl i '''''''*;'''''' :// ' ' ' '''. :',. ' '''''.71:.,',..4r.k, 0^ - .41001010 .www Page 13 Version 0 June,2015 • 0 HSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 11.0 Drill 9-7/8" Hole Section 11.1 P/U 9-7/8" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 9-7/8" BHA(GR and Res LWD are included in below BHA): COMPONENT DATA Item Description Serial Number OD ID Gauge Weight Top Length Cumulative I (in) (in) (in) (lbpf) Connection (ft) Length (ft) MI HOBS MM65 PDC 7.000 2.500 9-875 114.43 P 4112"REG 090 090 © r SperryDrill Lobe 7r8-6.0 stg 7 000 4.952 93.13 B 4112"!F 26 40 27.30 - Stabilizer -__ 9625 _--- © 6-3.:4"NM Stabilizer 6 750 3.063 8.750 96 84 B 4-1;2"IF 7.00 34.30 © 6-314"Float Sub 6 750 2.813 100 78 B 4-1/2"IF 2.20 36.50 ® 6-314"DM Collar(Directional) 6 750 3-125 103 40 B 4-112"IF 9 20 45.70 6 6 3'4"DGR Collar tGamma) - 6.750 1.920 97.80 B NC 50 4.55 50.25 a 6 3.14"EWR-P4 Collar(Resistivity) - 6 750 2.000 104.30 B NC 50 12.10 62.36 Q 6 3+4"PWD(Pressure) - 6 750 1-905 96.30 B 4-1;2"IF 4.44 66.79 - 6 314"HCIM Collar(Processor) 6 750 1.920 101.70 B NC 50 4 97 71 76 10 6 3+4"ALD Collar iDensity) 6.750 1.920 8 250 104 30 B 4-112"IF 14.54 86.30 - Stabilizer -__ 8 250 _--- ® 6 34"CTN Collar(Porosity; 6 750 1.905 102.30 B 4-112"IF 1' 84 98 15 ® 6-3;4"TM Collar(Telemetry I - 6 750 3.250 103.60 B 4-112"IF 10 00 108.15 ® 6-3,4"Non Mag Flex Collar 6 750 2 813 100.78 B 4-1±2"IF 30.00 Min Egi 6-3r4"Non Mag Flex Collar 6 750 2.813 100.78 B 4-1;2"IF 3000 168.15 ® 6-3r4'Well Commander Sub 6 750 3.000 97.86 B 4-112"IF 1300 18' 15 m X/O 4.5"IF P x 4.5"CDS 4013 6.500 2.750 92.85 B 4.5"CDS 2.75 183 90 40 ® 4 x jts 4.5"HWDP 4.500 2.813 33.02 120.00 303.90 18 Xr0 4.5"CDS 40 P x 4.5"IF B 6.500 2.750 92.85 B 4-112"IF 2.50 306.40 ® 6_1:4"Weatherford Jar 6 250 2.313 90 24 B 4-12"IF 30.00 336.40 20 X.'0 4.5"IF P x 4.5"CDS 40 B 6.500 2.188 10027 B 4.54'OCDS 3.00 339.40 ® 15 x jts 4.5"HWDP 4.500 2.813 33.02 450 00 789.40 789.4 Page 14 Version 0 June,2015 0 • SRU 213-15 Drilling Procedure Rev 0 Hilcor 11.3 Primary Bit: 9-718" (251mm) MM65 PRODUCT SPECIFICATIONS Cutter Type SeleetCurter IADG Coda M323 e Body Type MATRIX 'total Cutter C'uunt i 46 a ,,.4,„1.4 Cutter Distribution I tmm j( 4' t Face tl 214 A Gauge 12 0 xil Up Drill 6 U Nuraber of Large Nozzles 6 Number of Medium Nooks 4 ge Number ofSmall Nozzles 4 di Number of Micro Nozzles 4 • r Number of Pons(Sine) 4 Number of Replaceable Porl Sire) 4 3 ta Junk Slot Area l M)in) 16.71 — Normalized Face Volume 45.41 ',; API Connection 4-I 2 REG.PIN Recommended Make-Up Torque' 12,461-17,766 Felbs. A! A Nominal Dimensions•• Make-Up Face to Nose 10.81 in-275 min flange Length 2.5 in.64 mm Sleeve Length 0 in-0 nim Shank Diameter 6 in-152 nen Break Out Plate f Mat.M+Legncytl i 18145444040 Approximate Shipping Weight 2SOLba.-113 Kg. SPECIAL FEATURES Up-Drill Cutlers on Gage Pauls..1.'16"Relieved Gage Material#771827 •11it'pacific recommended makeup torque is a titmice either bit I.D.and actual bit sub O.D.etiliml as specified in API RP7G Section A.$.2. **Design dimenraona arc tuamtevt and tray vary slightly on nwnutactured pnstuss.llunihurron Drill hire and Services finale's are unnitnunusl}resieacd and rcttned Product specifications may change without notice. C 2013 Halliburton.All rights reserved.Saks of Nallibunon products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 15 Version 0 June,2015 • S SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 11.4 4-1/2" Workstring &HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 13-3/8" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 9-7/8" hole section to 2,500' MD/2,248' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500- 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale between 2400' MD and 2600' MD. • • Take MWD surveys every stand drilled (60' intervals). 11.7 9-7/8" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1) ppg above highest anticipated MW. We will start with a simple gel+FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 120-2500 8.8—9.5• 85-150 20-40 25-45 <10 8.5-9.0 v Page 16 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L/DEXTRID LT if required for<12 FL ALDACIDE G 0.1 ppb X-TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 13-3/8"conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 9-7/8"hole section. Page 17 Version 0 June,2015 • • ,„ SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 12.0 Run 7-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 7-5/8" casing running equipment. • Ensure 7-5/8"BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total# of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on(thread locked). • (1) Joint with coupling thread locked. • (1) Joint with float collar bucked on pin end &thread locked. • Install(2) centralizers on shoe joint over a stop collar. 10' from each end. • Install(1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 7-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install(1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft-lbs Page 18 Version 0 June,2015 SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy company Casing and Tubing Performance Data PIPE BODY DATA GEOMETRY Outside Diameter 7.625 in Wall Thickness 0.375 in API Drift Diameter 6.750 in Nominal Weight 29.70 lbs/ft Nominal ID 6.875 in Alternative Drift Diameter n.a. Plain End Weight 29.06 lbs/ft Nominal cross section 8.541 in PERFORMANCE Steel Grade 180 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Tension Yield 683,000 in Internal Pressure Yield 6,890 psi Collapse Pressure 4,790 psi Available Seamless Yes Available Welded No CONNECTION DATA TYPE:BTC GEOMETRY Coupling Reg OD 8.500 in Threads per in 5 Thread turns make up 1 PERFORMANCE Steel Grade 180 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 6,890 psi 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 0 June,2015 • • ral SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company u,l�- L'Ij 13.0 Cement 7-5/8" Surface Casing ` 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • Pump 20 bbls of freshwater through all of Schlumberger's equipment,taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50%open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol(BELS) Vol(ft3) 12.0 ppg LEAD: 120' x.0932 bpf= 11.2 63 13-3/8" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD: (2000' — 120')x .0382 bpf x 107.7 605 9-7/8" OH x 7-5/8" Casing 1.5 =- annulus:annulus: Total LEAD: 118.9 668 ft3 15.4 ppg TAIL: (2500'-2000') x.0382 bpf x 28.7 161 9-7/8" OH x 7-5/8" Casing 1.5 = annulus: 15.4 ppg TAIL: 80 x.04591 bpf = 3.7 31 7-5/8" Shoe track: Total TAIL: 34.2 bbl 192 ft3 Page 20 Version 0 June,2015 • • HSRU 213-15 Drilling Procedure Rev 0 Hilc_orp 13.0 Cement 7-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable -_,tes. • Pump 20 bbls of freshwater through all of Schlumberger's equi' /ent,taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluis ill be fed to displacement pump. • Positions and expectations of personnel involved with t cmt operation. 13.2 Document efficiency of all possible displacement pum prior to cement job 13.3 R/U cmt head (if not already done so). Ensu Q op .nd bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surfa t ines. 13.5 Pump remaining 30 bbls of 10 pp: ..ace 13.6 Drop bottom plug. Mix •is c • per below reci e. 13.7 Cement volume based o nnular olume 50%o ole excess. Job will consist of lead & tail, TOC brought to surface. Estima d Total Cement Volume: Section: Calculation: Vol (BBLS) Vol(ft3) 12.0 ppg LEAD: iy 120' x.0932 bpf= 11.2 63 13-3/8" Conductor x 7-5/8" casing annulus: 12.0 ppg LEAD ' (2000' — 120') x .0382 bpf x 2 <.6 1317 9-7/8"OH x 7-5/8"Cas.'g 1.5 = annu s: Total L AD: 24 8 bbl 1380 ft3 56b-54'- 15.4 x15.4 ppg AIL: (2500'-2000')x .0382 b. ` x 2, 7 161 9-7/8"OH x 7-5/8"Casing .5 = nnulus: 15.4 ►'i g TAIL: 80 x .1 591 bpf = 3.7 31 7-5/8" hoe track: 'otal TAIL: 34.2 bbl 192 ft3 1 5'7s' ` f Page 20 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp enact Company Cement Slurry Design: Lead Slurry(2000' MD to surface) Tail Slurry (2000' to 2500' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk V 1.22 ft3/sk " Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk Additives D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2%BWOC D046 Anti Foam 0.2%BWOC D065 Dispersant 0.4%BWOC D079 Extender 2.0%BWOC 5002 CaCl2 0.35%BWOC D020 Extender 3.0%BWOC D177 CaCl2 0.1%BWOC 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets"sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with spud mud. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 2500'- 80' =2420' x.04591 bpf= 111 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. V Page 21 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 13.13 Do not overdisplace by more than 1/2 shoe track volume. Total volume in shoe track is 3.7 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12— 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to fmal circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail, volume&weight • Pump rate while mixing,bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume, whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job . Send final `As-Run"casing tally&casing and cement report to cdinger@Jzilcorp.com and mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/U Seaboard multi-bowl wellhead assy. Install 7-5/8"packoff P-seals. Test to 3000 psi. 14.2 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install(2) manual valves&a check valve on kill side of mud cross. • Install(1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.3 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.4 R/D BOP test assy. 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 9.0 ppg 6%KCL PHPA mud system. 14.7 R/U mud loggers for production hole section. 14.8 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. Page 23 Version 0 June, 2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 15.0 Drill 6-3/4" Hole Section 15.1 Pull test plug, run and set wear bushing 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Ensure to have enough 4-1/2" DP in derrick to drill ;, the entire open hole section without having to pick up pipe from the pipeshed. Page 24 Version 0 June,2015 • SRU 213-15 Drilling Procedure Rev 0 Hilcor Bony 15.7 6-3/4" BHA: COMPONENT DATA �I, IR Item OD ID Stiff ID Gauge Weight Top Length Total Location Description (in) (in) (in) (in) (Ibpf) ft)pnnection (f() ( (ft) 1 HOBS EM65D PDC 4.500 2250 6.750 40.65 P 3-112"REG 0.80 2 5"SperryDnil Lobe 617-6.0 stg 5.000 3.120 3.120 48.00 B 3-112"IF 23 20 24_00 3 4-3,4'Float Sub 4750 2.250 1.000 46.84 B 3-12"IF 2 20 26 20 4 4-3,4'DM Collar(Directional) 4-750 2.610 2.638 47.00 8 3-112"IF 9 20 35 40 5 4-3.4"SP4 Collar(Gamma 8 Resistivity) 4.750 1.250 3.280 4820 B 3-1;2"IF 24.57 59.97 6 4-3.4'ALD Collar(Density) 4.750 1.250 2.696 6 000 45.50 B 3-1;2"IF 14.35 74.32 67.31 Stabilizer 6 000 67.31 7 4-3.4'CTN Collar lPorosityj - 4.750 1.250 1 853 50.50 B 3-1;2"IF 11 14 85.46 8 4-314'TM Collar(Telemetry) - 4.750 2.812 3.039 46.10 _ B 3-1;2"IF - 11.00 96.46 9 4-3.4"Non Mag Flex Collar 4.750 2.250 46.84 B 3-112"IF 30.00 126.46 10 4-3'4'Non Mag Flex Collar 4.750 2.250 46.84 B 3-112"IF 30.00 156.46 11 3.5'IF P x 4.5'CDS 40 8 5.300 2.250 2.250 61.64 8 4.5'4 i l2" 2 50 158,96 CDS 40 12 2 xjts 4.5"HWDP 4.500 2.750 41.00 60,00 218.96 13 4.5'CDS 40 P x 3.5"IF 8 5-300 2.200 2250 62.23 8 3-112"IF - 2 50 221.46 14 4.75"Weatherford Jar 4.800 2.250 2.250 48.12 B 3-112"IF 30 00 251.46 15 3.5"IF P x 4.5"CDS 40 8 5.250 2.250 2.250 60.22 B 4.5'4 1.2" 2 50 253.96 CDS 40 16 17 x its 4.5"HWDP 4.500 2.750 41.00 510.00 763.96 Total: 763.96 Page 25 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 15.8 Primary Bit: 6-3/4" (171mm) EM65D PRODUCT SPECIFICATIONS Cutter Type K3-Extreme Drilkittg .« �, IADCCodc M323 11110414 ' Body Type MATRIX �/ p , Total('utter Count 33 Cutler Distribution 1 1� face 4 13 t " Gauge 11 1 Up Skill 5 0 Number of Large Nozzles 0 Number of Medium Nozzles tl er Number of Small Nozzles t * • Number of Micro blanks ti :Ar 0, =.a Number of Pons(Sim) a Number of Replaceable Ports lSize) 0 ' (17 Junk Slot Arca i sq in) SAS t" Norm Irted Face Volute 34.69% = r API Connection 3-Ir'REG.PIN e tis- Recommendeii Make-Up Torque* 5.173-7,665 Ft'Ibs. Nominal Dimensions** Make-Up Face to Nose 9.42 in-239 nn Gauge Length 2 in-St mm Sleeve Length 0 in-0 mm • Shank Diametet 4i in-114 mit Break Out Plate IMat.MJLegarybl 114195344030 Approximate Shipping Weight 90Lbs.-4I Kg. SPECIAL FEATURES Up-Drill Cutlers on Gage Pads,1.'16"Stepped Gage.Optimized Dual Row-"D"Feature Material tt761302 *Bit specific recoirunended nuke-up torque ix s rum-non of the hit I.D.and admit bit sub Q.D.initiated as specirted in All RP7(i Section A.x.2. **Design dimensions are nominal and tray sen^slightly on msoutiuwred prrducs.Holtiluamn[hill Hits and Services models are continuously'ewe...seal and retired Product WOOEreati.Mts may vintage aithoui'Halve. .2013 Halliburton.All rights reserved.Saks of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 26 Version 0 June,2015 • I SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 15.9 6-3/4" hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1) ppg above highest anticipated MW. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 6%KCL PHPA fresh water based drilling fluid. Properties: MD ud Viscosity Plastic Yield Point pH HPHT Weight 1 Viscosity 2500'-5,043' 9.0—10.0 , 40-53 15-25 15-25 8.5-9.5 <11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCl 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.0—10.0 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.10 TIH w/6-3/4"directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC requirement is 50% of burst. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. Page 27 Version 0 June, 2015 • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy company 15.14 Conduct FIT to 11.5 ppg EMW. Note: Offset field test data predicts fr• radient at the 7-5/8"shoe to be between 11 - 13 ppg EMW. An 11.5 ppg FIT results i a 2.5 .pg kick margin while drilling with the planned MW of 9.5 ppg. <tr.s--9.$) a" 731 15.15 Drill 6-3/4"hole section to 5,043' MD. C l X. 447 • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 225 - 300 gpm. Ensure shaker screens are set up to handle this flowrate. • `t • Keep swab and surge pressures low when tripping. K.J- Thfr " • Make wiper trips every 500' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed • necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 15.16 At TD;pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 15.17 TOH with the drilling assy, standing back drill pipe. 15.18 LD BHA, RU E-line to perform RFT logging run and log well. 15.19 RD loggers, PU 6-3/4"clean out BHA, and TIH to TD. 15.20 Pump sweep, CBU and condition mud for casing run. 15.21 POOH LDDP and BHA 15.22 Install 4-1/2"pipe rams in BOP stack and RU and test. Page 28 Version 0 June,2015 • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 16.0 Run 4-1/2" Production Casing 16.1. R/U Weatherford 4-1/2"casing running equipment. • Ensure 4-1/2"DWC/C HT x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted prior to running. • Be sure to count the total# of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor &model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 4-1/2" production casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 7-5/8" shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 2000'. 16.5. Continue running 4-1/2" production casing 4-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5,800 ft-lbs 6,500 ft-lbs 7,200 ft-lbs r/ Page 29 Version 0 June,2015 • S SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWCIC Tubing 4-112 in 12.60 lb/ft(0.271 in) L-80 staidard Material L-80 Grade WM° 80.000 Minimum Yield Strength (psi) MI 11111111111N USA 95.000 Minimum Ultimate Strength (psi) VAIN USA 4424 W.Sam Houston Pkvry.Suite 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 4.500 Nominal Pipe Body O.D. (in) Fax:713-479-3234 3.958 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsaiesavam-usa.com 0.271 Nominal Wall Thickness(in) 12.60 Nominal Weight (lbs./ft) 12.25 Plain End Weight(lbsift) 3.600 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength (lbs) 7.500 Minimum Collapse Pressure (psi) 8.430 Minimum Internal Yield Pressure(psi) (` 7.700 Hydrostatic Test Pressure (psi) g; Connection Dimensions 5.000 Connection O.D. (in) ). 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter (in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 288.000 Joint Strength (lbs) 14.290 Reference String Length (ft) 1.6 Design Factor 314.000 API Joint Strength (lbs) 288.000 Compression Rating (lbs) 7.500 API Collapse Pressure Rating (psi) 8.430 API Internal Pressure Resistance (psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-lbs) 6,500 Maximum Final Torque(ft-lbs) 7.200 Connection Yield Torque (ft-lbs) Page 30 Version 0 June, 2015 • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 16.6. Run in hole w/4-1/2"casing to the 7-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,000 feet to the shoe or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 4-1/2"X 6-3/4" swell packer to be placed at approximately 2000'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 31 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 17.0 Cement 4-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud &water can be delivered to the cmt unit at acceptable rates. • Pump 20 bbls of freshwater through all of Schlumberger's equipment,taking returns to cuttings bin, prior to pumping any fluid downhole • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35%OH excess. Vol Section: Calculation: (BBLS) Vol(ft3) 7-5/8"x 4-1/2"Csg Overlap: 500' x 0.026 = 13 73 6-3/4"OH x 4-1/2"Casing: (5043 —2500)x 0.025 x 1.5 = 95 533 Shoe Track: 80' x 0.019= 1.5 Total Volume : 109.5 615 LtSZ s� Page 32 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company EASYBLOK (5043' to 2500') • System Conventional Density 15.3 lb/gal Yield 1.36 ft3/sk -✓ Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2%BWOC D202 Dispersant 1.5%BWOC Additives D400 EASYBLOK 0.8%BWOC • D154 Extender 8.0%BWOC D174 Expanding Additive 1.5%BWOC D198 Retarder 0.3%BWOC 17.7. Drop wiper plug and displace with 3% KCl. 17.8. If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns&pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than''Y2 shoe track. Shoe track volume is 1.5 bbls. 17.12. Bleed pressure to zero to check float equipment. Watch for flow.Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 1 17.14. WOC minimum of 12 hours,test casing to 3000 psi and chart for 30 minutes. Page 33 Version 0 June,2015 • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume& weight • Pump rate while mixing,bpm, note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume, whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally&casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. c)44 TA . )14— lg. .445 Page 34 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig #169 Page 35 Version 0 June,2015 9 • HSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 19.0 BOP Schematic 1 1 1 3.5" Modet O1ti 1111 iii 1111 �III Taj 0H ��. t 3;ner®Y ��._I- - va_, Mode17UR2 s _-4 ��, 1 v 5,,,,,, :milli H J_ ■■■■■■ {1j' iii itlell it' rre 2.00' 0 ` y 161 ill i!1 i!1 I!1 ,_-+ - 2 1/111 SM Kdl Side '�3 1/S 5M Choke Side rr= i 1 3f =nu. 1 41 c� / _ Medai l: — i!t: Ille &I • ._,.. , 1!1 11111111 lel lel ' (-rade 1f1 161 111 I!1 lei _j1, : N. 43' ; 0 • SRU 213-15 HDrilling Procedure Rev 0 Hilcorp Energy Company 20.0 Wellhead Schematic BHTA,Ota,61/16 SM FE a 6.5 Cots qutr=vmon top 11— .1.111101 1.1111..11 A Valve,Swab,OW F[ • 41/1654.1 FE,IMO • EE trim _l I"" • Vave,Wigg,CIW-iC, Valve.,SSV,Barber,3118 SM •�,•� 31/6 SM FE,IVO, FE.w/garner kydraulir:self a�Tk` EE trim contained operate, 111.11111.1 Cross.stili,41/165M x ! .411111111114111 4s 3 1/g 5M -� %i 'i ""5"1/....Svalve,Upper Master, CIW FC,41/16 SM FE,HtVO, Y~• EE trim • ..;‘,.,,.....• 1• I. sal ur;., A • valve,Mast,,OW FC, 41/16 SM FE,Hww0, C.,-'y4 EE trim •C., -1.4 , 1 I MR Tub Tub 1g Mad Cactus C N. ;f Btu HP5,13 5/83M a 11SM,wf •.ai�I t _ �i8i•- 2-2 I/16 5M 550 TIM :I�: 1 : I. :II Start ighead,CxtusC-294 •9a 0 `Is` ilii1iNgla•il!a- 13 Sig 3M a T33/B Sow,w/ 2-211165M 550 i NO •Page 37 Version 0 June,2015 SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 SRU 213-15 loco 2000 -- s 3000 � t 3 �Np 2 4000 i {R 5000 _ 6000 _ -4 0 2 4 6 8 10 12 14 16 18 DOW Page 38 Version 0 June,2015 • 0 HSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME. SRU 213-15 FIELD: Swanson River s(1RA-ACEX 348893.19 STATE Alaska 2480102.04 J47900.00 T`dKB . c <: $... �DREFDA ,y 2474400.00 rID REF ELEV 335 18'KB(Saxon 169) NAD2i GROUND ELEV 317.3 5043.I0 MO 4738.5 TVD Drill a grass root well in to test the Sterling and uppper Beluga gas potential. . l Based on subsurface evaluation EXPECTED Formation FORMATION FLUID MD TVD Est Pressure EMW f/c._rz/l, 64,21, At KOP 790 800jf , SR A9ST Sand Gas 3166 2528 997 7.6 SR_AlOST Sand Gas 3301 2661 1051 7.6 SR_BOST Sand Gas 3468 2828 800 5.4 SR_B1ST Sand Gas 3510 2870 925 6.2 1' SR_B2ST Sand Gas 3558 2918 800 5.3 SR_B3ST Sand Gas/Water 3593 2954 1190 7.7 SR_B3-A2_ST Sand Gas 3664 3024 1100 7.0 SR_B3-L_ST Sand Gas 3710 3070 200 1.3 SR_B4ST ' Sand Gas 3756 3116 1282 Z9 SR_B4X Sand Gas 3803 3163 350 2.1 SR_BSST Sand Gas 3843 3203 1200 7.2 SR_ Sand Gas 4015 3375 1325 7.5 SR_B7ST Sand Wet 4156 3516 1468 8.0 - SR 36-9A2 ST Sand Wet 4247 3607 700 3.7 SR_36-9AST Sand Gas 4314 3674 1100 5.8 SR_36-9ST Sand Gas 4103 3463 1200 6.7 SR_38-OST Sand Gas 4502 3862 1150 5.7 SR_38-4ST Sand Gas 4519 3879 1450 • 7.2 Primary Objective =Secor!dary Ob(ective TARGET RADIUS 30 FT DATA COLLECTION REQUIREMENTS: JMuq Logging 4 man Crew below conductor. t-WD Data -Line Log Data Quad-Combo with Dipole Sonic. 30 RFT pressures ' COMPLETION TYPE Gas lift completion ANTICIPATED RATES 2000 bpd gross fluid ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2 Mr Page 39 Version 0 June, 2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 23.0 Anticipated Drilling Hazards 9-7/8" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material&500 lbs different sizes of Calcium Carbonate are . available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. • Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of-50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 40 Version 0 June,2015 • • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 6-3/4" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: • Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6%KCI in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: 4 H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 41 Version 0 June,2015 1 • S HSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 24.0 Saxon Rig 169 Layout fel .413 _M MICMi Milli Ips 11III + FF'Ei«F ItIMMItIA 1 11111.-=:.-- 11 i� Milli! .'�°'°�,ani II.,...E= - EMI _-_Mil , I 4 M'T•f �, - �� t%,1 :71-1711� i 1.1 Di-- II In g a .. . im;,.. III i.l 1,‘..,03 a:.:ass. - H1 %IiaeMrTrr »• 44,..11 ..w.rr_ r - r - 1 Jill!] u; � I L - 1 I .i„F,..,Fa.N.r.,,n IiM, 1 1 Page 42 Version 0 June, 2015 S • SRU 213-15 Drilling Procedure Rev 0 Hilcorp Ene`gy Company 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20'of new formation below the casing shoe (this does not include rat hole below the shoe). • 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 43 Version 0 June, 2015 I • HSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 26.0 Choke Manifold Schematic i I g ,.A • il S _ P /„- 1, ` ,., [� P P i /fir , i im ll aE' i `t cif. _ 0 _.i_Ariy- a ia 7,r'''' , i' i. ill i , , isio P ...t7" fit oT . '''';.1 .411. a „.,- 17:::, : _ 3 ti'; '-- y: n Ar >} H o1...:1?: _1 firti74 111111111111111 ,,JJ mile _.. 0 it,., lit' ..;),.. .A t t Q o . Ili 1111 e r L. _ L IP 09 L— E411 I la leip . I Page 44 Version 0 June,2015 • • El. SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 27.0 Casing Design Information Calculation&Casing Design Factors Swanson River Unit DATE:6/9/2015 WELL:SRU 213-15 FIELD:Swanson River DESIGN BY: Monty M Myers Design Criteria: Hole Size 9-7/8" Mud Density: 8.8 ppg Hole Size 6-3/4" Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1236 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 1298 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient extemal stress(0.435 psi/ft)and the casing evacuated for the intemal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 7-5/8" 4-1/2" Top(MD) 0 0 Top(TVD) 0 0 Bottom(MD) 2,500 5,043 Bottom(TVD) 2,247 4,739 Length 2,500 5,043 Wei.ht(..t) 29.7 12.6 Grade L-80 L-80 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 74,250 63,542 Tension at Top of Section(lbs) 74,250 63,542 Min strength Tension(1000 lbs) 683 288 Worst Case Safety Factor(Tension) 9.20 " 4.53 • Collapse Pressure at bottom(Psi) 977 2,061 Collapse Resistance w/o tension(Psi) 4,790 7,480 Worst Case Safety Factor(Collapse) 4.90 a 3.63 ' MASP(psi) 744 1,062 Minimum Yield(psi) 6,890 8,430 Worst case safety factor(Burst) 9.26 - 7.94• Page 45 Version 0 June,2015 • 0 HSRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 6-3/4" Hole Section MASP IIMaximum Anticipated Surface Pressure Calculation Hilcor� 6-3/4"Hole Section SRU 21315 Swanson River Unit MD TVD Planned Top: 0 0 Planned TO: 5043 4739 ,44►441-1441 452 . r) Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad KOP 790 ' ' '' %•r- SR_A9ST 2528 997 Gas 7.6 0.394 O `O'© —ry SR_A105T 2661 1051 Gas 7.6 0.395 SR_BOST 2828 800 Gas 5.4 0.283 SR_B1ST 2870 925 Gas 6.2 0.322 SR_B2ST 2918 800 Gas 5.3 0.274 SR_B3ST 2954 1190 Gas/Water 7.7 0.403 SR_B3-A2_ST 3024 1100 Gas 7.0 0.364 SR_B3-L ST 3070 200 Gas L3 0.065 SR_B4ST 3116 1282 Gas 7.9 0.411 SR_B4X 3163 350 Gas 2.1 0.111 SR_BSST 3203 1200 Gas 7.2 0.375 SR_B6ST 3375 1325 Gas 7.5 0.393 SR_B7ST 3516 1468 Wet 8.0 0.418 SR_36-9A2_ST 3607 700 Wet 3.7 0.194 SR_36-9AST 3674 1100 Gas 5.8 0.299 SR_36-9ST 3463 1200 Gas 6.7 0.347 SR_38-0ST 3862 1150 Gas ___15. SR_38-4ST 3879 1450Gas ( 7.2 '' Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date SCU 21-4 12 ppg 0 10,965 1961 SCU 44-33 113-12.5 ppg 9,216 10,747 2013 SCU 41A-4 112 ppg 9,300 10,807 2013 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 6-3/4"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. Fracture Pressure at 7-5/8"shoe considering a full column of gas from shoe to surface: TVD Frac Grad 2247 ft X 0.650 psi/ft 1461 psi 1461(psi)-[0.1(psi/ft)*2247(ft)]= 1236 psi i,v MASP from pore pressure during production mode(Complete evacuation to gas) .1.z,C 4739 ft X 0.374 psi/ft 1772 psi 1772(psi)-[0.1(psi/ft)'4739(ft)]= 1298 psi 'r Sunvnary: 1 MASP while drilling 63/4"production hole is governed by frac pressure at 7-5/8"shoe Page 46 Version 0 June, 2015 • II SRU 213-15 Drilling Procedure Rev 0 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) 1 I Q co A028405 SRL'_34-1C BHL SRU 21-15 BHt SRU_31-15 BHL• SRU 241-16 BHL• \ SRU_41A-15 BHLSV. 1 SRL'213-15 S11L •SRU'242-Ib BHL 3 12-44 • S�32A4t5 BH!• 0o01#* SRU"42-15 BHL• o°°o C SRU 32C-15 BHL► (#.:SR211— IS T ' PUA028384 A028077 SWANSON RIVER UNIT 1-41SRU 213-15 BBL _.._..,,_____- PL SRU_33-15 BHL• SOOSN009W SRU_z3,sBHLa SRU 33-15BHUt ISRU_43-15RD BHL•-- / 1 I�rt�p,tAC A028408 • ��/ 1 r 1 f 1 1s I (•�}SRU 34-1613141. _ _� SRU_14.15emt r r r• r ,rr Legend rr� • SRU 213-15 SHL .•r rr X SRU 213-15 TPH r rs # SRU 213-15 BHL SRU_21-22 BHL Ela E i SRU_11.22 BHL• Other Surface Well Locations I�4 • Other Bottom Hole Locations Well Paths 00 and Gas Untt Boundary - II a 1.aot� z.c,.�_� Swanson River Unit Feet SRU 213-15 Alaska State Plane Zane 4 NAD27 A !tricorn%Loa.1.LC Map Date 4,1812015 Page 47 Version 0 June,2015 • • SRU 213-15 II Drilling Procedure Rev 0 Hilcorp Energy Company 30.0 Surface Plat (As Staked) (NAD 27) 9 10 SECTION LINE I I 16 15 N 2482273.79 NOT TO SCALE .f E 347878.31 1 w 1 1 i._\, Z UAS-STAKED WELL Z NORTH SRU 213-15 LL _ Z N:2480102.042 N r ( 't 0 0 E:348893.186 N • I— LATITUDE:60°47'08.688"N U ~ 'W LONGITUDE:150'50'44.159 cn Z ASP ZONE 4 NAD27 ® 15 r7:FNL=2158• FWL=1041'ELEV=317.3'(NAVD88) SECTION 15,T8N,R9W,SM,AK/ / C / ```%•%1I l l l RU 24246 .....`ANN:',;..4,F. QF q�gs�fa 1041'FWL /N:2480116.269 • I • 1 �, E:348822.248 �a SRU 12-15 i* f /\ * � / e N:2480090.800 ... 49 E:348941.05� t / •M. SCOTT MtLANE = �' �I `' •• 4928—S / 41 • ~ N 2480002 225 SRU 32A t5 ��'gyp :+�"a;;$.4 + / E:348872.347 N.2 7 Ii11\...• TANK SETTING 2-15 r- NOTES \ N''...-- -r / 11 BASIS OF COORDINATES NGS OPUS _.� If(( SOLUTION FROCORS•ZANE'.•TBON•AND '1155A'ALASKA STATE PLANE ZONE 4 NAD�83 41 EPOCH 2003 / 2)BAStS OF ELEVATNON-NGS BM 079 RESET / 1991 NAVOB6. V , 3)SECTION LINE OFFSETS COMPUTED FROM / ` 8LM CORNERS FOUND E Xe S9 516 ALONG '4 NORTH SEC.LITE OF St6 8 NE CORNER SEC.IT / /� `N'P USED TO COMPUTE NORTH LINE OF SEC.15 / \0 SHOWN. THE WEST LINE OF SEC.t5 WAS COMPUTED FROM SE CORNER OF SEC.15 / FOUND 4)CORPSCON VERSION 6.0.I SOFTWARE WAS // / \ \ UTILIZED FOR CONVERSIONS BETWEEN �,QATUMS(NAD63 TO NAD27). / // I , SCALE i \\ \ SRU 213-15 AS-STAKED SURFACE LOCATION (NAD27) SWANSON RIVER FIELD TS 2-15 PAD LOCATION:SECTION 15. TOWNSHIP 8 NORTH ESURVEYINGNGINEERING-MTESTINGAPPING RANGE 9 WEST.SEWARD MERIDIAN ALASKA - P.O.BOX 468 11,1,orp Ua•L,.1.1.1 4111 G, SOLOOTNA,AK.99869 JOB NO 157005 VOICE-19071283.4218 FAX:(907)283-3265 DWG. Can l Inc WWW.MCVWECG.COM 157005 Date:4/24/2015 FIGURE: 1 Page 48 Version 0 June,2015 • i °m SRU 213-15 Drilling Procedure '. ' Rev 0 Hilcorp Energy Company 31.0 Surface Plat (As Staked) (NAD 83) 9 10 SECTION LINE _ I I 1 6 1 5 N 2482035 75 NOT TO SCALE E 1487901.69 I I __ I I w NORTH W —' Z Q AS-STAKED WELL Z p J 0 SRU 213-15 I J ,: Z N:2479863.861 F. E:1488916.543N I P LATITUDE:60°47'06.67"N I W 0 LONGITUDE: 150°50'52.15"W CP 15 U3Z ASP ZONE 4 NAD83FWL= 1041 �^ /111)FWL=1041' / ELEV=317.3'(NAVD88) SECTION 15,T8N,R9W,SM,AK/ 1041 / FWL /SKI : 479878 091 ` �Q'.(E O l A(:46N f-it "i / 14888405 604 ,, SRU 12-15 ..- *:49 JEW. ' N2479846.378 4. E:1488981 11$ .4 -4 :r44/17 _ & i / i / A t,M. SCOTT McLANE;�8 ',, I `rr•- .0, 4928-5 / SRU 241-16 RU 32A-15 i .1 i `�_— N:2479764.040 N2479796.270 1I yq� s oto:,-. "V�` c E 1488845 187 E1488910.801 ,(1 l‘‘‘.0% ` TANK SETTING 2-15 " - S (UT OF COORDINATES'RATEA'NGS 11 t { Y SOLUTION FROM CORS'LW 1',"TBOrt'�.•a' 'TSEA'ALASKA STATE PLANE ZONE 4'AIJE.I / EPOCH 2003. 90 2)8A51$CP ELEVATION'NGS EM 079 RESET / 0 0 ` 1991 NAVD66. 31 SECTION LINE OFFSETS COMPUTED FROM / \ttP ELM CORNERS FOUND E y{,,S9 S16 ALONG 3 NORTH SEC LINE OF Ste&NE CORNER SEC ' / // \9rj\ USED TO COMPUTE NORTH UNE OF SEC 15 SHOWN THE WEST LME OF SEC-15 WAS COMPUTED FROM SE CORNER OF SEC 15 // / \ \ OUND. / 0100 200 \\ / I SCALE I \ \ SRU 213-15 AS-STAKED SURFACE LOCATION (NAD83) SWANSON RIVER FIELD TS 2-15 PAD H LOCATION.SECTION 15, TOWNSHIP 8 NORTH- ENGINEERING-TESTING RANGE 9 WEST,SEWARD MERIDIAN ALASKA SURVEYING-MAPPING 44.,::-,I P.O.BOX 468 Ililrnrp \la,6a.l.1.( McLANC. SOLooTNA.AK.99664 JOB NO 157005 iimappr VOICE (907)283-4218 FAX_(907)283-3265 DWG. Gm1a*1n/INC WWW MCLANECG COM 157005 Date:4/24/2015 FIGURE: 1 Page 49 Version 0 June, 2015 • ! Hilcorp Energy Company Swanson River Unit Swanson River Unit Plan: Swanson River Unit 213-15 SRU 213-15 Plan: SRU 213-15 wp3 Standard Proposal Report 09 June, 2015 HALLIBURTON Sperry Drilling Services • Project: Swanson River Unit WELL DETAILS: Plan:Swanson River Unit 213-15 NAD 1927(NADCON CONUS) Alaska Zone 04 HALLIBUPTON Site: Swanson River Unit Ground Level: 317.30 Well: Plan: Swanson River Unit 213- +NI-S +E/-W Northing Easting Laum de Longitude Slot Sperry Mining Wellbore: SRU 213-15 0.00 0.00 2480017.20 348756.50 60.7855097 -150.8463585 Plan: SRU 213-15 wp2 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Plan:Swanson River Unit 213-15,True North -240— Vertical(TVD)Reference:Plan SRU 213-15 @ 335.30usft Measured Depth Reference:Plan SRU 213-15(81 335.30usft Calculation Method:Minimum Curvature 0- 240- 480— 600 5° 720— 10° 15° 960— �0gj0 25 1200— 50 Nfo 1440— 1680— 5� _ 000 - rL 1920- 7 - o - 02160— 00 t 75/8"---. -225 W2400— 20° 0 SRU 213-15 wp2 A9 Tgt 2640— 15° 3000 it 2880- 5° 3120— °---- SRU 213-15 wp2 64 Tgt 3500 3360- 3600— 4000 3840— SRU 213-15 wp2 38-0 Tgt 4080— 4500 4320- 4560- 5 1/2"_, -5000 4800— SRU 213-15 wp2 5040—i -1440 -1200 -960 -720 -480 -240 0 240 480 720 960 1200 1440 1680 1920 2160 2400 2640 2880 Vertical Section at 233.48°(600 usft/in) 2481300- SRU 213-15 Csg D. SRU 12-15 Csg Detail • TVD MD Name Size TVD MD Name Size 2247.3 2500.0 7 5/8" 7-5/8 3168.2 3168.3 13 3/8" 13-3/8 2481150- 4738.4 5043.0 4 1/2" 4-1/2 11382:191383.3 7" 7 SRU 241-16 Csg Detail SRU 242-16 Csg Detail 2481000- TVD MD Name Size 62.8 62.8 16" 16 TVD MD Name Size 1384.7 1549.3 9 5/8" 9-5/8 2109.1 2327.3 9 5/8" 9-5/8 3632.7 4260.3 7" 7 3991.8 4820.3 7" 7 2480850- SRU 32A-15 Csg Detail 2480700- TVD MD Name Size 2964.3 2964.3 13 3/8" 13-3/8 U 241-16 2480550- 2480400- 9 5/8" 2480250- C) c O 9 5/8" ^$ 13 3/8" SRU 12-15 O Z 2480100- i�:i o c ' /8" SRU 32A-15 - 2000 v-SRU 242-16 2479950— O 2479800— V. to `mo 2479650— 5/8"/ 1] 2479500_771.7 SRU 213-15 2479350— 2479200- 2479050- I I f I f I I 1 I I f 348150 348300 348450 348600 348750 348900 349050 349200 349350 349500 349650 Easting HALLIBURTQN Project: Swanson River Unit WELL DETAILS: Plan:Swanson River Unit 213-15 Sperry Drilling Services Site: Swanson River Unit Ground Level: 317.30 Well: Plan: Swanson River Unit 21 +N/-S +E/-w Northing Easting Latittude Longitude Slot Wellbore: SRU 213-15 0.00 0.00 2480017.20 348756.50 60.7855097 -150.8463585 Plan: SRU 213-15 wp2 REFERENCE INFORMATION Co-ordinate(WE)Reference:Well Plan:Swanson River Unit 213-15,True North Vertical(TVD)Reference:Plan SRU 213-15 335.30usft Measured Depth Reference: Plan SRU 213-15©335.30us11 Calculation Method:Minimum Curvature 400— 300— 200- 100- 0— 250 o°o -100- - _ o -200— _ So0 .E • -300— S - s N -400- - • 7 5/8" -500— • J s 00 51/2" -600— • s$ - SRU 213-15 wp2 r 4739 • _ r 700- - i ` ••r • • -800— I \ I SRU 213-15 wp2 49 TgI' CASING DETAILS • • I SRU 213-15 wp2 38-0 Tglt SRU 213-15wp2 B4Tg{ TVD TVDSS MD Size Name 2266.98 1931.68 2501.30 7-5/8��,/ 7 5/8" -900— 4724.26 4388.96 4985.74 5 1fR n( 1z ' 'L- -1000- -1100- - / l, M Azimuths to True North _ /\ Magnetic North:16.84° -1200— _ Magnetic Field Strength:55477.3snT Dip Angle:73.76° Date:3/31/2015 Model:BGGM2014 - I I I I I I I I I I I I I I I I I I I I I I I l I I l l I I I j l l I l I I I I l I l I J I I I I I I I I I I I I I I I I I I I I -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 West(-)/East(+)(200 usft/in) In I l il►•t wi) I r Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:Swanson River Unit 213-15 Company: Hilcorp Energy Company TVD Reference: Plan SRU 213-15 @ 335.30usft Project: Swanson River Unit MD Reference: Plan SRU 213-15 @ 335.30usft Site: Swanson River Unit North Reference: True Well: Plan:Swanson River Unit 213-15 Survey Calculation Method: Minimum Curvature Wellbore: SRU 213-15 Design: SRU 213-15 wp3 Project Swanson River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Swanson River Unit Site Position: Northing: 2A65,597.40 usft Latitude: 60.7460001 From: Map Easting: 346,899.00usft Longitude: -150.8557002 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.75° Well Plan:Swanson River Unit 213-15 Well Position +N/-S 0.00 usft Northing: 2,480,102.04 usft • Latitude: 60.7857466 +E/-W 0.00 usft Easting: 348,893.19 usft• Longitude: -150.8455999 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: - 317.30 usft Wellbore SRU 213-15 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) () (nT) BGGM2014 3/31/2015 16.84 73.76 55,477 Design SRU 213-15 wp3 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +N/-S +E/•W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 234.01 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) (°/1OQusft) (°/100usft) (°) 18.00 0.00 0.00 18.00 -317.30 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 -35.30 0.00 0.00 0.00 0.00 0.00 0.00 1,098.19 31.93 233.77 1,057.52 722.22 -128.09 -174.79 4.00 4.00 0.00 233.77 2,571.21 31.93 233.77 2,307.69 1,972.39 -588.55 -803.14 0.00 0.00 0.00 0.00 2,820.15 22.00 235.50 2,529.30 2,194.00 -654.04 -894.89 4.00 -3.99 0.70 176.24 3,142.45 9.11 236.05 2,839.14 2,503.84 -702.68 -966.10 4.00 -4.00 0.17 179.61 3,165.13 9.11 236.05 2,861.53 2,526.23 -704.69 -969.08 0.00 0.00 0.00 0.00 3,392.85 0.00 236.83 3,088.30 2,753.00 -714.78 -984.06 4.00 -4.00 0.00 180.00 4,167.85 0.00 236.83 3,863.30 3,528.00 -714.78 -984.06 0.00 0.00 0.00 0.00 5,043.08 0.00 236.83 4,738.52 4,403.22 -714.78 -984.06 0.00 0.00 0.00 236.83 6/9/2015 4:07:34PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:Swanson River Unit 213-15 Company: Hilcorp Energy Company TVD Reference: Plan SRU 213-15 @ 335.30usft Project: Swanson River Unit MD Reference: Plan SRU 213-15 @ 335.30usft Site: Swanson River Unit North Reference: True Well: Plan:Swanson River Unit 213-15 Survey Calculation Method: Minimum Curvature Wellbore: SRU 213-15 Design: SRU 213-15 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (') (') (usft) usft (usft) (usft) (usft) (usft) 417.30 18.00 0.00 0.00 18.00 -317.30 0.00 0.00 2480,102.04 348,893.19 0.00 0.00 100.00 0.00 0.00 100.00 -235.30 0.00 0.00 2,480,102.04 348,893.19 0.00 0.00 200.00 0.00 0.00 200.00 -135.30 0.00 0.00 2,480,102.04 348,893.19 0.00 0.00 300.00 0.00 0.00 300.00 -35.30 0.00 0.00 2,480,102.04 348,893.19 0.00 0.00 400.00 4.00 233.77 399.92 64.62 -2.06 -2.81 2,480,100.02 348,890.35 4.00 3.49 500.00 8.00 233.77 499.35 164.05 -8.24 -11.24 2,480,093.95 348,881.84 4.00 13.94 600.00 12.00 233.77 597.81 262.51 -18.50 -25.25 2,480,083.87 348,867.70 4.00 31.30 700.00 16.00 233.77 694.82 359.52 -32.80 -44.76 2,480,069.82 348,848.01 4.00 55.49 800.00 20.00 233.77 789.91 454.61 -51.06 -69.68 2,480,051.88 348,822.86 4.00 86.38 900.00 24.00 233.77 882.61 547.31 -73.20 -99.89 2,480,030.14 348,792.36 4.00 123.84 1,000.00 28.00 233.77 972.47 637.17 -99.11 -135.24 2,480,004.69 348,756.68 4.00 167.66 1,098.19 31.93 233.77 1,057.52 722.22 -128.09 -174.79 2,479,976.21 348,716.76 4.00 216.70 1,100.00 31.93 233.77 1,059.05 723.75 -128.65 -175.56 2,479,975.66 348,715.98 0.00 217.65 1,200.00 31.93 233.77 1,143.93 808.63 -159.91 -218.22 2,479,944.95 348,672.93 0.00 270.54 1,300.00 31.93 233.77 1,228.80 893.50 -191.17 -260.87 2,479,914.24 348,629.87 0.00 323.42 1,400.00 31.93 233.77 1,313.67 978.37 -222.43 -303.53 2,479,883.54 348,586.81 0.00 376.31 1,500.00 31.93 233.77 1,398.54 1,063.24 -253.69 -346.19 2,479,852.83 348,543.76 0.00 429.19 1,600.00 31.93 233.77 1,483.41 1,148.11 -284.95 -388.85 2,479,822.12 348,500.70 0.00 482.07 1,700.00 31.93 233.77 1,568.28 1,232.98 -316.21 -431.50 2,479,791.41 348,457.65 0.00 534.96 1,800.00 31.93 233.77 1,653.15 1,317.85 -347.47 -474.16 2,479,760.70 348,414.59 0.00 587.84 1,900.00 31.93 233.77 1,738.03 1,402.73 -378.73 -516.82 2,479,730.00 348,371.53 0.00 640.73 2,000.00 31.93 233.77 1,822.90 1,487.60 -409.99 -559.47 2,479,699.29 348,328.48 0.00 693.61 2,100.00 31.93 233.77 1,907.77 1,572.47 -441.25 -602.13 2,479,668.58 348,285.42 0.00 746.50 2,200.00 31.93 233.77 1,992.64 1,657.34 -472.51 -644.79 2,479,637.87 348,242.36 0.00 799.38 2,300.00 31.93 233.77 2,077.51 1,742.21 -503.77 -687.45 2,479,607.17 348,199.31 0.00 852.27 2,400.00 31.93 233.77 2,162.38 1,827.08 -535.03 -730.10 2,479,576.46 348,156.25 0.00 905.15 2,500.00 31.93 233.77 2,247.26 1,911.96 -566.29 -772.76 2,479,545.75 348,113.19 0.00 958.04 2,501.30 31.93 233.77 2,248.36 1,913.06 -566.70 -773.32 2,479,545.35 348,112.63 0.00 958.72 7 5/8" 2,571.21 31.93 233.77 2,307.69 1,972.39 -588.55 -803.14 2,479,523.88 348,082.54 0.00 995.69 2,600.00 30.78 233.91 2,332.28 1,996.98 -597.39 -815.23 2,479,515.20 348,070.33 4.00 1,010.67 2,700.00 26.79 234.51 2,419.91 2,084.61 -625.56 -854.27 2,479,487.54 348,030.93 4.00 1,058.81 2,800.00 22.80 235.31 2,510.67 2,175.37 -649.68 -888.57 2,479,463.86 347,996.32 4.00 1,100.74 2,820.15 22.00 235.50 2,529.30 2,194.00 -654.04 -894.89 2,479,459.58 347,989.94 4.00 1,108.42 2,900.00 18.81 235.57 2,604.13 2,268.83 -669.79 -917.84 2,479,444.13 347,966.80 4.00 1,136.24 3,000.00 14.81 235.69 2,699.84 2,364.54 -686.11 -941.70 2,479,428.11 347,942.73 4.00 1,165.14 3,100.00 10.81 235.90 2,797.33 2,462.03 -698.58 -960.02 2,479,415.89 347,924.25 4.00 1,187.29 3,142.45 9.11 236.05 2,839.14 2,503.84 -702.68 -966.10 2,479,411.86 347,918.11 4.00 1,194.62 3,165.13 9.11 236.05 2,861.53 2,526.23 -704.69 -969.08 2,479,409.89 347,915.11 0.00 1,198.21 3,200.00 7.71 236.05 2,896.03 2,560.73 -707.54 -973.31 2,479,407.10 347,910.84 4.00 1,203.30 3,300.00 3.71 236.05 2,995.51 2,660.21 -713.10 -981.56 2,479,401.65 347,902.52 4.00 1,213.25 3,392.85 0.00 236.83 3,088.30 2,753.00 -714.78 -984.06 2,479,400.00 347,900.00 4.00 1,216.26 3,400.00 0.00 0.00 3,095.45 2,760.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 3,500.00 0.00 0.00 3,195.45 2,860.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 3,600.00 0.00 0.00 3,295.45 2,960.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 6/9/2015 4:07:34PM Page 3 COMPASS 5000.1 Build 73 • 4110 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan:Swanson River Unit 213-15 Company: Hilcorp Energy Company TVD Reference: Plan SRU 213-15 @ 335.30usft Project: Swanson River Unit MD Reference: Plan SRU 213-15 @ 335.30usft Site: Swanson River Unit North Reference: True Well: Plan:Swanson River Unit 213-15 Survey Calculation Method: Minimum Curvature Wellbore: SRU 213-15 Design: SRU 213-15 wp3 Planned Survey I Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (") (^) (usft) usft (usft) (usft) (usft) (usft) 3,060.15 3,700.00 0.00 0.00 3,395.45 3,060.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 3,800.00 0.00 0.00 3,495.45 3,160.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 3,900.00 0.00 0.00 3,595.45 3,260.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,000.00 0.00 0.00 3,695.45 3,360.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,100.00 0.00 0.00 3,795.45 3,460.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,167.85 0.00 236.83 3,863.30 3,528.00 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,200.00 0.00 0.00 3,895.45 3,560.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,300.00 0.00 0.00 3,995.45 3,660.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,400.00 0.00 0.00 4,095.45 3,760.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,500.00 0.00 0.00 4,195.45 3,860.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,600.00 0.00 0.00 4,295.45 3,960.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,700.00 0.00 0.00 4,395.45 4,060.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,800.00 0.00 0.00 4,495.45 4,160.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 4,900.00 0.00 0.00 4,595.45 4,260.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 5,000.00 0.00 0.00 4,695.45 4,360.15 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 5,028.81 0.00 0.00 4,724.26 4,388.96 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 5 1/2" 5,043.08 • 0.00 236.83 4,738.52 • 4,403.22 -714.78 -984.06 2,479,400.00 347,900.00 0.00 1,216.26 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) SRU 213-15 wp2 38-0 Tgt 0.00 0.00 3,863.30 -714.78 -984.06 2,479,400.00 347,900.00 -plan hits target center -Point SRU 213-15 wp2 A9 Tgt 0.00 0.00 2,529.30 -714.78 -984.06 2,479,400.00 347,900.00 -plan misses target center by 100.57usft at 2857.77usft MD(2564.36 TVD,-661.76 N,-906.13 E) -Circle(radius 200.00) SRU 213-15 wp2 B4 Tgt 0.00 0.00 3,117.30 -714.78 -984.06 2,479,400.00 347,900.00 -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 2,501.30 2,248.36 7 5/8" 7-5/8 9-7/8 5,028.81 4,724.26 5 1/2" 5-1/2 8-1/2 6/9/2015 4:07:34PM Page 4 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company Swanson River Unit Swanson River Unit Plan: Swanson River Unit 213-15 SRU 213-15 SRU 213-15 wp3 Sperry Drilling Services Clearance Summary Anticollision Report 09 June,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Swanson River Unit-Plan:Swanson River Unit 213-15-SRU 213-15-SRU 213-15 wp3 Well Coordinates: 2,480,102.04 N,348,893.19 E(60°47'08.69"N,150°50'44.16"W) Datum Height: Plan SRU 213-15 @ 335.30usft Scan Range: 0.00 to 5,043.52 usft.Measured Depth. Scan Radius is 1,702.55 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Version: 5000.1 Build: 73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services • • Hilcorp Energy Company HALLI B U RTO N Swanson River Unit Anticollision Report for Plan: Swanson River Unit 213-15-SRU 213-15 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:Swanson River Unit-Plan:Swanson River Unit 213-15-SRU 213-15-SRU 213-15 wp3 Scan Range:0.00 to 5,043.52 usft.Measured Depth. Scan Radius is 1,702.55 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Swanson River Unit Plan:Swanson River Unit 212B-15-SRU 2128-15-SR 300.00 77.25 300.00 75.44 300.00 42.620 Ellipse Separation Pass- Plan:Swanson River Unit 212B-15-SRU 212B-15-SR 575.00 96.74 575.00 93.65 572.50 31.311 Clearance Factor Pass- Plan:Swanson River Unit 213B-15-SRU 213B-15-SR 250.00 153.89 250.00 152.30 250.00 96.922 Ellipse Separation Pass- Plan:Swanson River Unit 213B-15-SRU 213B-15-SR 1,450.00 296.22 1,450.00 282.32 1,300.00 21.304 Clearance Factor Pass- Swanson Riv Unit 241-16-SRU 241-16-SRU 241-16 586.68 80.22 586.68 59.42 578.30 3.858 Centre Distance Pass- Swanson Riv Unit 241-16-SRU 241-16-SRU 241-16 625.00 80.83 625.00 58.57 613.65 3.631 Ellipse Separation Pass- Swanson Riv Unit 241-16-SRU 241-16-SRU 241-16 725.00 88.66 725.00 62.59 704.91 3.402 Clearance Factor Pass- Swanson Riv Unit 432-15-SRU 32A-15-SRU 32A-15 636.91 39.48 636.91 33.89 632.51 7.062 Centre Distance Pass- Swanson Riv Unit 432-15-SRU 32A-15-SRU 32A-15 650.00 39.60 650.00 33.88 645.23 6.921 Ellipse Separation Pass- Swanson Riv Unit 432-15-SRU 32A-15-SRU 32A-15 675.00 40.57 675.00 34.61 669.43 6.807 Clearance Factor Pass- Swanson Riv Unit 432-15-SRU 432-15-SRU 432-15 636.91 39.48 636.91 33.89 627.51 7.062 Centre Distance Pass- Swanson Riv Unit 432-15-SRU 432-15-SRU 432-15 650.00 39.60 650.00 33.88 640.23 6.921 Ellipse Separation Pass- Swanson Riv Unit 432-15-SRU 432-15-SRU 432-15 675.00 40.57 675.00 34.61 664.43 6.807 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 18.00 5,043.07 SRU 213-15wp3 MWD+SC+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 09 June,2015-16:08 Page 2 of 4 COMPASS • • Hilcorp Energy Company HALL I B U RTO N Swanson River Unit Anticollision Report for Plan: Swanson River Unit 213-15-SRU 213-15 wp3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan SRU 213-15 @ 335.30usft. Northing and Easting are relative to Plan:Swanson River Unit 213-15. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00°,Grid Convergence at Surface is: -0.74°. Ladder Plot F r I I C I I I I I 1 I 1 1 11 I • 1 1 I 1 7 r 1 1 cAi 4� Zar.trar�+ 41LEGEND 111111111111 'r X1111ca --- --- �� - Ran:SwansonRineerUnA212B-15,SRU2126-15,SRU2126-15tip a- % Pan:SwansonRiverUnit213B-15,SRU213B-15,SRU-213B-15et dwanson Riv Und241-16,SRU 241-16,SRU 241-16 VO ;v Pr/r1 d = swansonRivUnd432-15,SRU 32A-15,SRU 32A-15V0 //�� = 9rransonRivUnit432-15,SRU 432-15,SRU 432-15V0 A U 11 = 8211213-15wp3 i -i O 1 1 ,'I� ' I iU I I U Zt% 1 0 _ X1_ 7 1 0 900 1800 2700 3600 4500 Measured Depth(900 usft/in) 09 June,2015- 16:08 Page 3 of COMPASS Hilcorp Energy Company HALLI B U RTO N Swanson River Unit Anticollision Report for Plan:Swanson River Unit 213-15-SRU 213-15 wp3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor 1o.00 6.75 1 --------- :_ 7.so c - 0 625 LEGEND 8 - -fr Plan:Swanson River Unit212B-15,SRU 212B-15,SRU21213-15wp, LL - 0 5.00--_ - -r-Plan:SwansonWar Unit2136-15,SRU 213B-15,SRU-213B-15wp; '� -I- Swanson RivUnit241-16,SRU241-16,SRU241-16V0 _ $-Swanson RivUnit432-15,SRU32A-15,SRU32A-15V0 3.75 -e-SwansonRivUnit432-15,SRU 432-15,SRU 432-15V0 - $ SRU 213-15,61)3 2.50 _ Collision Avoidance Req —N�4f Zone-Stop Drilling __- 0.00- 1111 1 i ' 1111 i i i 1111 1111 1111 1111 1111 1111 1111 1111 1 0 425 850 1275 1700 2125 2550 2975 3400 3825 4250 4675 5100 M6Rsued Dep h(853 usft1n) 09 June,2015- 16 08 Page 4 of 4 COMPASS • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,June 16, 2015 9:26 AM To: mmyers@hilcorp.com Cc: 'Davies, Stephen F (DOA) (steve.davies@alaska.gov)' Subject: RE: SRU 213-15 (PTD 215-100) Monty, Check the surface casing volumes too ... 7 5/8" casing. I think your excess is a bit high for what you normally pump. Guy Schwartz Senior 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(Guy.schwartz@alaska.gov). From: Schwartz, Guy L (DOA) Sent: Tuesday, June 16, 2015 9:19 AM To: mmyers@hilcorp.com Cc: 'Davies, Stephen F(DOA) (steve.davies@alaska.gov)' Subject: FW: SRU 213-15 (PTD 215-100) Monty .. Sorry this was for you.. Guy Schwartz Senior 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(Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Tuesday, June 16, 2015 9:16 AM To: Luke Keller Cc: 'Davies, Stephen F(DOA) (steve.daviesCa alaska.gov)' Subject: SRU 213-15 (PTD 215-100) Luke, As you are requesting a Diverter waiver please provide a spider map showing the surface casing points for the wells on the pad as well as the proposed 213-15.The provided spider map is not detailed enough. ... 1 Guy Schwartz • • Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIAL11Y 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(Guy.schwartz@alaska.gov). 2 S • Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday,June 12, 2015 5:07 PM To: Davies, Stephen F (DOA) Subject: Re: SRU 213-15 (PTD#215-100) We plan to only run gr/res. My fault. Selected wrong BHA Monty M Myers 907.538.1168 On Jun 12, 2015, at 11:27 AM, Davies, Stephen F (DOA) <steve.davies@alaska.gov<mailto:steve.davies@alaska.gov» wrote: Monty, I'm reviewing the Permit to Drill application for SRU 213-15. On page 14,the BHA component data table for the 9-7/8" hole section includes pressure, density and neutron collars, but both Line 11.2 immediately above that table and the Reservoir Evaluation Plan on page 7 list only GR+ Res LWD for this surface hole section. Which is correct? Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov<mailto:steve.davies@alaska.gov>. 1 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: 173 '—/-C PTD: - —��Development —Service Exploratory Strati�a hic Test Non-Conventional — FIELD: � iC�E�-ice 5�!1{ 0-64--- POOL: " mace c') L,Ci -t Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 5/2013 • • 0 0 Q N Na. _ N N a) ❑ O O , I- a m co a). 0 0, O (O, CIOw. c .p , acr a, m, O' E m m' E , a) co �, o E O r ro, o. f6 v. 3. o, L. . , y. a) N' m i o' m a 2' c , : • • • • , : : : +' f6' 3. : o a). v. 0, ai, 2' c a a N to O 3, O N CO , N'. ar V, fC. a) o) 7-' -c5' , U , E. C, m N. 0 �. C) C9, m. a, 0. o, 3, CO, U. - �, p c C , O, m, or a. 3, , ,, p. a o 0. > a vi. x co Co J. G cn - �, w o, Q, 3. �' o m. C' g E' a > o, CO M W' , Ca U ?�� •O' y. a=. -O, ' Co. y O' W' �� O, 0. -2' y. O) N N. X. C, 0 a), :. , 00• , `), . .0, >, Co 0f 0 , f`, �. N. co. 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' ' 4- 4- N N N N N N N N N N CO M CO CO CO CO CO CO CO CO O H ,- c p C °: coN a,) 0) ON 0 o x co 0 0 as N O ❑ ° ❑ N 0 0 O w a p [ p N E J N aO] 0 J xt •- a s c a J -oo a a 0 " aIa a w a 0 U a U) • • Well History File APPENDIX Infoimation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1 SRU 213-15 50-133-20652-00-00 Kenai Gas Field Kenai Peninsula Borough, Alaska September 11, 2015 – September 17, 2015 Provided by: Approved by: Jacob Dunston Compiled by: Tollef Winslow Craig Silva Distribution Date: October 16, 2015 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3 1.1 Equipment Summary ...................................................................................................................... 3 1.2 Crew ............................................................................................................................................... 3 2 GENERAL WELL DETAILS ................................................................................................................... 4 2.1 Well Objectives ............................................................................................................................... 4 2.2 Hole Data ........................................................................................................................................ 4 2.3 Daily Activity Summary ................................................................................................................... 5 3 GEOLOGICAL DATA ............................................................................................................................. 8 3.1 Lithostratigraphy ............................................................................................................................. 8 3.2 Lithology Details ............................................................................................................................. 9 3.3 Sampling Program ........................................................................................................................ 12 4 DRILLING DATA .................................................................................................................................. 13 4.1 Surveys ......................................................................................................................................... 13 4.2 Bit Record ..................................................................................................................................... 15 4.3 Mud Record .................................................................................................................................. 16 4.4. Drilling Progress ........................................................................................................................... 17 5 SHOW REPORTS ............................................................................................................................... 18 6 DAILY REPORTS ................................................................................................................................ 19 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Computers – Surface Logging (3) Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 0 Ditch gas QGM gas trap; Flame ionization total gas & chromatography. 4 Hours After failure of the initially emplaced legacy QGM gas trap motor, a new trap was installed, which continued to run without incident for the remainder of operations. Hook Load / Weight on bit WITS from Pason 0 Mud Flow In Calculated value derived from Strokes/Minute and Pump Output 0 Mud Flow Out WITS from Pason 0 Pit Volumes, Pit Gain/Loss WITS from Pason 0 Pump Pressure WITS from Pason 0 Pump Stroke Counters (2) WITS from Pason 0 Rate of Penetration Calculated from Pason 0 RPM WITS from Pason 0 Torque WITS from Pason 0 WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Tollef Winslow 7 10 Doug Merkert 6 3 Craig Silva 37 10 Karen Austin 4 3 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. 4 2 GENERAL WELL DETAILS 2.1 Well Objectives SRU 213-15, a grassroots gas development well, was permitted to be directionally drilled in a planned S- Path from the SRU 32-15 pad. A newer subsurface modeling and seismic interpretation, supported by the field’s historical production data, indicated recoverable stranded gas reserves within an extended section of Lower Sterling and Upper Beluga sands. Proven undeveloped (PUD) reserves, still exploitable in Lower Sterling sands, are the objectives of SRU 213-15. A new well was required to overcome both take-point limitations, and the progressive and problematic deterioration of mechanical conditions in the aging adjacent wells that would otherwise be candidates for re-entry. Operator: HILCORP ALASKA, LLC Well Name: SRU 213-15 Field: Swanson River Field, Swanson River Unit County: Kenai Peninsula Borough State: Alaska Company Representatives: Rance Pederson, Shane Hauck, Shane Barber, Marvin Rogers Location: Surface Coordinates 2158’ FNL, 1041’ FWL, Sec 15, T8N, R9W, SM, AK Ground ( Pad ) Elevation 317.3’ AMSL Rotary Table Elevation 335.9’ AMSL Classification: Single Zone Development Gas API #: 50-133-20652-00-00 Permit #: 215-100 Rig Name/Type: Saxon 169 / Land / Double Spud Date September 11, 2015 Total Depth Date: September 17, 2015 Total Depth 4470’ MD / 4162’ TVD Primary Targets Reserve Zones in the Lower Sterling and Upper Beluga Primary Target Depths Up to 14 known potential Primary Targets Total Depth Formation: Beluga Completion Status: 4.5” Casing LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Services Schlumberger 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth FIT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 9 7/8” 2525 2265 Sterling 9.2 32.11 7 5/8” 2520 2260 11.5 6 ¾” 4470 4163 Beluga 9.0 1.10 4 ½” 4465 4156 - 5 2.3 Daily Activity Summary September 10, 2015: The rig continued to prepare to drill: The rig was assembled and spud mud built. September 11, 2015: The rig finished installing all equipment and was accepted by Hilcorp rep at 02:30. Pick up and rack back 2300’ of 4 ½” drill pipe in the derrick. Hold safety meeting with Hilcorp and the Bureau of Land Management. Pick up four more stands (eight joints) of 4 ½” drill pipe and rack it back. Pick up eight stands of 4 ½” HWDP and rack back. Make up bit and motor. The motor bend was changed and the motor scribed. The LWD and MWD tools were picked up and programmed. The well was spudded at 13:58. The rig drilled ahead, rotating and sliding, from 120’ to 639’. September 12, 2015: Drill ahead, sliding and rotating from 639’ to 1196’. Wiper Trip to clean the hole from 1196’ to 200’. Tight spots encountered at 900’, 839’, 715’, 670’, 594’, 535’ and from 460’ to 320’. Maximum overpull during the wiper trip of 20K. The tight spots were either in clay or coal formations. Run back in the hole on elevators. Wash and ream from 720’ to 903’ and from 1070’ to 1200’. 21 units of wiper gas were observed on bottom. Drill ahead, sliding and rotating from 1200’ to 1255’. Perform high viscosity sweep which yielded 25% increase in cuttings. Continue rotating and sliding as per directional driller from 1255’ to 1880’. Pump around Hi-Vis sweep with 50% increase in cuttings at surface. Do wiper trip from 1880’ to 1257’ with no tight spots. Run back to bottom (1880’) and drill ahead. 45 units of wiper gas were observed. Drilled ahead, rotating and sliding, from 1880’ to 2114’ as of report time. September 13, 2015: Drill ahead rotating and sliding from 2114’ MD to 2520’ MD. Bottom of 9 7/8” hole section in sandstone. Circulate bottoms up and pump around high vis sweep. The sweep returned with minimal increase in cuttings. Drill another five feet to 2525’ MD. Circulate bottoms up. Pull out of hole on wiper trip from 2525’ MD to 200’ MD. No tight spots observed. Run back in hole from 200’ to apparent tight zone at 990’. Wash and ream from 990’ to 1005’. Continue running in hole on elevators from 1005’ to 2439’. Wash and ream from 2439’ to bottom at 2525’. Circulate bottoms up and pump around Hi-Vis sweep. Observed 43 units of wiper gas. Continue to circulate and condition hole. No increase in cuttings was observed. Perform flow check (static). Pull out of hole from 2525’ to 270’. Break and lay down jars and flex collars. Plug in and download MWD recorded data. Break and lay down remaining BHA. Drain motor. Break bit. Lay down motor and bit. Pull wear bushing. Flush well head. Pick up landing joint and check well head depth. Hold safety meeting with casing crew. Begin rig up. Change out elevators and elevator links in preparation for running 7 5/8” casing. Weatherford power tools and slips were rigged up. Prep rig floor to run casing. Run 7 5/8” in casing as per Hilcorp procedures (to 2267’at report time). September 14, 2015: Continue to run 7 5/8” casing from 2267’ to 2495’. Circulate bottoms up and continue circulating while changing out to long bails. Record 6 units of trip gas. Rig down all Weatherford casing running equipment. Hold pre job meeting with all hands on safety and procedures for cement job. Pick up the hanger and landing joint and land the casing at 2520’. Continue to circulate and condition drilling fluid in preparation for cementing the casing. Record 9 units of trip gas. Rig up cementing head and all other Schlumberger cementing equipment. Switch over to Schlumberger pumping unit. Pump 15 bbls of water and pressure test cementing lines to 1200psi low / 5000psi high. Pump 36 barrels of 10.0 pound per gallon (ppg) mud push. Drop bottom plug. Pump 157.0 bbls of 12.0 ppg lead cement, and follow with 43.0 bbls of 15.4 ppg tail cement. Drop top plug. Displace with initial 10.0 bbls of water and follow with 112.0 bbls of 9.2 ppg spud mud. Bump plug with 1250psi, hold for 3 minutes and then bleed off 0.5 bbls. Cement in place at 04:52 Hrs. Rig down all Schlumberger cementing equipment. Back out landing joint. Install pack-off. Lay down landing joint, casing elevators, and long bails. Rig down flow line and hole fill line. Nipple down and lay out riser. Nipple down DSA spool. Install well head. Install test plug. Pressure test well head to 500psi for 5 minutes and 5000psi for 15 minutes. Pick up and set spacer spool. Finish installing spacer spool and pick and set BOPE. Install kill and HCR lines. Hook up accumulator lines. Charge accumulator and BOP stack. Fill BOP stack and choke manifold. Test all BOPE. The State of Alaska witness of the BOP test was waived by Jim Regg while the Bureau of Land Management chose to witness the BOP tests. Continue testing BOPE. 6 September 15, 2015: Continue and complete testing of all BOPE. [Test Sequence: #1 – annular/Hydril (test failed); #1 retest - annular/Hydril to 250psi Low / 2500psi High for 10 minutes (pass test); note all other BOPE testing to 250psi Low / 3500psi High for 10 minutes; #2 - upper pipe rams, CMVs 1-3-5-7, mez. kill valve, dart valve (test failed, > cycle and grease mez. kill valve, change out valve on test manifold, ); #2 re-test - upper pipe rams, CMVs 1-3-5-7, mez. kill valve, dart valve (pass test); #3 – CMVs 2-6-8, kill HCR, TIW valve (TIW valve failed); #3 retest – CMVs 2-6-8, kill HCR (pass test); #4 – CMVs 9- 11-13, inside kill (CMV 11 failed, > cycle and grease valve); #4 retest – CMVs 9-11-13, inside kill (pass test); #5 – choke, HCR, lower TIW valve on TDS; #6 – inside choke valve; #7 – electric power choke; #8 – manual choke; #9 – lower pipe rams; perform accumulator drawdown test (1450psi and 92 second recovery starting with 3100psi, > four-bottle avg. of 2650psi); #10 – blind rams, CMVs 10-12]. Level rig. Strap 66 joints of 4 ½” drill pipe and 2 joints of 4 ½” HWDP. Set flow nipple. Pick up/make up bit and motor. Scribe motor. Pick up/make up remaining directional BHA. Uplink to MWD collar and pulse test tools. Load nuclear sources. Pick up/make up flex collars. Continue running in hole with BHA to 812’. Pick up 14 joints of 4 ½” drill pipe and rack 7 stands back. Continue running in hole from 812’, singling in 52 joints of 4 ½” drill pipe to 2400’. Break circulation. Condition mud and circulate surface to surface volume. Wash to 2413’ and stop circulating. Rig up at surface and perform pressure test of casing to 3200psi for 30 minutes. Drill out cement and shoe tract from 2413’ to 2430’. Drill out float equipment. Drill ahead from 2525’ to 2545’ (20’ of new hole) to perform LOT. Displace spud mud with KCl mud. Rig up and perform Leak Off Test to 11.5 lb/gal EMW. Drill ahead, rotating and sliding, from 2545’ to 2622’. September 16, 2015: Drill from 2622’ to 3352’ (parameters: pick up weight 78 K-lbs, slack off weight 79 K-lbs, 54 K-lbs when rotating at 60-62 rpm, top drive torque 5-6 K ft-lbs, WOB 3 K-lbs, stand pipe pressure 1501 psi, flow in 325 gpm). Perform wiper trip from 3352’ to 2514’ with no tight spots. Trip back in the hole from 2514’ to 3352’, wash down last stand with no fill. Observe 88 units of wiper gas. Drill from 3352’ to 3385’ (parameters: WOB 3 K-lbs, stand pipe pressure 1600 psi, differential pressure 40 psi, top drive torque 5560). Continue drilling from 3385’ to 4027’ (with following parameters: WOB 4 K- lbs, stand pipe pressure 1867 psi, differential pressure 55 psi, top drive torque 8.8 K ft-lbs). Pump Hi-Vis sweep at 3430’ at theoretical with 50% increase in cuttings. Continue to drill from 4027’ to 4159’ (with following parameters: pick up weight 100 K-lbs, slack off weight 62 K-lbs, rotating weight 80 K-lbs, top drive torque 8400 ft-lbs, stand pipe pressure 1641 psi, flow in of 322 gpm. Circulated bottoms up two times and monitor well for losses. Well dropped 18” in 15 minutes for a 0.2 bbl loss. Perform wiper grip from 4159’ to 3293’ with no tight spots. The well took 1.76 bbls during the trip out. Run back in the hole from 3293’ to 4159’ (wash 2’ of fill to bottom). The well took 4.0 bbls during the trip in. Pump two complete bottoms up with a trip gas of 79 units. Drill from 4159’ to 4222’ (parameters: pick up weight 100K-lbs, slack off weight 62 K-lbs, rotating weight 79 K-lbs, top drive torque 8 K-lbs, WOB 2-3 K-lbs . September 17, 2015: Continue drilling ahead from 4222’ to final Total Depth of 4470’ MD (parameters: pick up weight 106 K-lbs, slack off weight 64 k-lbs, rotating weight 80 k-lbs, top drive torque 7-8 k ft-lbs, stand pipe pressure 1780 psi, pump output 327 gpm, top drive rate 80 rpm). Circulate bottoms up and monitor well. Observe 18” fluid drop in 15 minutes (total 0.2 barrels lost to the formation). Performed wiper trip from 4470’ to 2484’ (surface casing shoe). Hole took 6.16 barrels over theoretical during trip. Service rig and monitor well (record 1 bph loss until last 30 minutes of servicing when well was static). Trip back in the hole from 2484’ to bottom at 4470’. Circulate bottoms up and observe 41 units of wiper trip gas. Pump Hi-Vis sweep that returned on time with 25% increase in cuttings. Spot 23 barrel LCM pill on bottom. Perform flow check (wellbore static). Pull out of the hole from 4470’ to 2235’ with no overpull. Perform flow check at 2475’ during trip out (wellbore static). Continue to pull out of hole from 2235’ to 200’. Perform flow check (wellbore static). Lay down BHA. Pull sources. Link and download LWD memory data. Fluid losses to formation during trip out are 6.47 bbls. Hold pre-job procedures and safety meeting with Schlumberger Wireline Services personnel in preparation for running wireline tools. Spot wireline truck. Rig up sheaves and remaining wireline equipment. Run in hole with XPT (RFT) logging assembly. Log and perform pressure tests at pre-determined stations as per Hilcorp program. 7 September 18, 2015: Continue logging and complete logging program (perform 36 test point attempts from 4342’ to 2790’ and log 28 successful tests). Pull out of hole with XPT tool assembly. (Total mud losses during wireline operations 4.79 bbls). Pull, break and lay down logging tools and rig down all SWS wireline running equipment. Pick up/make up clean-out assembly. Run in hole with clean-out assembly to bottom at 4461’. Wash down last 9’ of fill to bottom at 4470’. Circulate bottoms up. Record 91 units of trip gas. Continue circulating. Rig generator, and Pason and Pitbull monitoring systems all went down. Continue circulating while troubleshooting system failures. Regain functioning of generator set and monitoring systems. Pump around a 17 bbl Hi-Vis sweep and observe 10% increase in cuttings on return. Circulate and clean hole. Pull out of hole from 4470’ laying down 4 ½” drill pipe. Continue to surface laying down clean-out BHA. No overpull on way out of hole. Hole took 9.28 bbls over theoretical. Clean and prep rig floor for running casing. Flush BOPs and wellhead. Drain stack. Pull wear ring. Prep landing joint, perform a dummy run. Rig up all Weatherford casing running equipment. Make up and run- in shoe track. Test floats. Run 4 ½” casing in the hole as per Hilcorp from surface to 1331’. Circulate bottoms up (with parameters: standpipe pressure 105 psi, flow in 134 gpm, MW 9.1. No stage gas was observed. September 19, 2015: Continue running 4 ½” casing from 1331’ to 2455’. Circulate out and observe 4 units of stage gas. Continue running 4 ½” casing in the hole from 2455’ to 3729’. Circulate out (with parameters: standpipe pressure 285 psi, flow in 235 gpm, MW 9.1). 29 units of stage gas were observed. Continue running 4 ½” casing from 3729’ to 4445’ Observe 7.0 bbl loss for entire casing run. Circulate bottoms up (with parameters: pick up weight 54 k-lbs, slack off weight 40 k-lbs, standpipe pressure 329 psi, flow in 234 gpm, MW 9.1). Record 29 units of trip gas. Make up hanger and landing joint. Continue circulating. Rig down Weatherford elevators and pull bushings. Run in with hanger and slack off. Land 4 ½” production casing with 18K string weight. (Shoe set at 4465.56’MD). Work pipe and circulate. Rig up Schlumberger cementing equipment and tools while continuing to circulate and work pipe. Prep cementing head with plugs. Hold pre-job meeting with all involved hands on safety and procedures for cement job. Test cement lines to 1000psi low and 5000psi high. Bleed off pressure to cementing unit. Pump 20 bbls of 12.5 ppg Mud Push II with rig pumps. Switch over and line up to Schlumberger pumping unit. Drop bottom plug and pump 51.6 bbls of 13.5 ppg lead cement (with 1 lb/bbl Cemnet added) and follow with 36.0 bbls 15.3 ppg tail cement. Pump 10 bbls water to flush lines to pits. Drop top plug and displace with 66.7 bbls of 8.5 ppg 3% KCL brine. Land hanger with 5 bbls to go and set down with 39K. Bump plug at 66.0 bbls into displacement (0.7 bbls early). Hold 500 psi over for 5 minutes. Bleed off pressure and check floats. Cement In Place at 09:31 hrs on 9-19-2015. Lost 15.0 bbls during displacement (90% returns). Wash through cement lines and rig down Schlumberger cementing equipment. Set pack-off tool and then perform successful test for 5 minutes at 5000 psi. Install back pressure valve in well head. Nipple down all BOPE equipment, nipple up tree and continue all Hilcorp-directed procedures for rig-down and preparation for move to next well at the same SRU 32-15 Pad location. 8 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Canrig Geologists. FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Sterling 508 508 -172 SR_A6ST 2561 2295 -1959 SR_A7ST 2689 2408 -2072 SR_A8ST 2766 2477 -2141 SR_A9ST 3166 2528 -2193 2817 2524 -2188 SR_A10ST 3301 2661 -2326 2968 2666 -2330 SR_A11ST 3052 2747 -2411 SR_B0ST 3468 2828 -2493 3166 2858 -2522 SR_B1ST 3510 2870 -2535 3211 2903 -2567 SR_B2ST 3558 2918 -2583 3253 2945 -2609 SR_B3ST 3593 2954 -2619 3291 2983 -2647 SR_B3-A2_ST 3664 3024 -2689 3348 3040 -2704 SR_B3-L_ST 3710 3070 -2735 3398 3090 -2754 SR_B4ST 3756 3116 -2781 3444 3136 -2800 SR_B4X 3803 3163 -2828 3490 3182 -2846 SR_B5ST 3843 3203 -2868 3518 3210 -2874 SR_B6ST 4015 3375 -3040 3664 3356 -3020 SR_B7ST 4156 3516 -3181 3811 3503 -3167 SR_36-9A2_ST 4247 3607 -3272 3898 3590 -3254 SR_36-9AST 4314 3674 -3339 3970 3662 -3326 Upper Beluga 4065 3757 -3421 SR_36-9ST 4403 3763 -3428 4100 3792 -3456 SR_38-0ST 4502 3862 -3527 4160 3852 -3516 SR38-4ST 4519 3879 -3544 4190 3882 -3546 9 3.2 Lithology Details As per Hilcorp direction, a Canrig-provided full service mudlogging program, with lithology descriptions of interval-collected rock cuttings samples in the Sterling and Beluga Formations, was initiated at the surface casing point (2525’ MD / 2264.53’ TVD). The Kenai Group formations of Alaska’s Cook Inlet Basin, which include the Sterling and Beluga, were deposited in a variable-energy fluvial system within a large closed fore-arc basin. The stratigraphic column consists of very dominant thin to massive sections of sandstone and claystone-siltstone, which are interrupted by extensively-distributed thinner zones of coal and carbonaceous rocks, locally to generally abundant thin layers of original and re-deposited volcanic ash, and minor beds of basal or modal conglomerate. Gradational upward-fining sequences and bi-modal zones are abundant within the sandstones. Nearly all soft-sediment Tertiary rocks in the Cook Inlet have been derived and/or very strongly influenced by vitric air-fall ash deposits sourced from continuously-forming volcanoes along the margins of the basin. Note that the special modifying term “tuffaceous” in Canrig Lithology Descriptions was created to address the diversity of volcanic-origin rocks in the Cook Inlet basin, and its use may include everything from discernible micro-shard concentrations of disaggregated volcanic glass to rare layers of vitric ignimbrite. Sand (2525'-2640') = medium dark gray to dark gray, slight salt/pepper appearance; upper fine to lower medium; spherical to sub-discoidal; sub-rounded to sub-angular; well to moderately well sorted; unconsolidated; texturally immature; quartz, translucent to transparent; moderate reddish brown lithics, grayish green lithics; porosity visually good. Tuffaceous Siltstone (2640'-2700') = medium light gray to medium gray with slight light olive gray sub hue; easily friable to soft; poorly indurated; crumbly to crunchy tenacity; sub-tabular to sub-nodular cuttings habit; earthy to dull luster; silty to gritty texture; massive or laminar structure; carbonaceous material; grainier siltstone locally transitional to lower very fine sandstone; coal, black, lignitic, mottled. Sand (2700'-2740') = medium dark gray to dark gray, salt/pepper in appearance; lower coarse to upper coarse, lower medium to upper fine, bimodal; sub-rounded to sub-angular; spherical to sub-discoidal; moderately sorted; unconsolidated; texturally immature; quartz, translucent to transparent; moderate reddish brown lithics, grayish green lithics, porosity visually good. Tuffaceous Siltstone (2740'-2840') = medium light gray to medium gray with light olive gray secondary hue; friable to soft; poorly indurated; tenacity crumbly to crunchy; earthy fracture; sub-nodular to sub- tabular cuttings; earthy to dull luster; silty to gritty texture; massive or laminar structure; carbonaceous laminations; siltstone locally transitional to lower very fine sandstone; coal, black lignite to sub-lignitic. Sand (2840'-2930') = dark gray to medium dark gray with overall salt and pepper appearance; upper medium to lower medium to occasionally coarse; spherical to sub-discoidal; sub-angular to sub-rounded; well to moderately well sorted; unconsolidated; texturally immature; quartz, translucent to transparent; orangish red lithics, black lithics, light olive green lithics; porosity visually good. Coal (2930'-2940') = brownish black to black; brittle tenacity; irregular fracture; elongated or planar or wedgelike cuttings habit; dense earthy to dull luster; matte texture; laminar structure; lignite to sub- lignitic; note common associated carbonaceous siltstone. Tuffaceous Siltstone (2940'-3000') = medium gray to medium light gray; easily friable to soft; poorly indurated; crunchy to crumbly tenacity; sub-nodular to sub-tabular cuttings habit; earthy to dull luster; silty to gritty texture; massive or laminar structure; associated sand, quartz: lower medium, moderately well sorted, spherical to sub rounded, black lithics, porosity visually good. 10 Sand (3000'-3040') = medium dark gray to dark gray with slight salt and pepper appearance; upper fine to lower medium; spherical to sub-discoidal; sub-rounded to sub-angular; well to moderately well sorted; unconsolidated; texturally immature; quartz, translucent to transparent; moderate reddish brown lithics, grayish green lithics; porosity visually good. Tuffaceous Siltstone (3040'-3100') = medium light gray to medium gray with light olive gray secondary hue; easily friable to soft; poorly indurated; crumbly to crunchy tenacity; earthy fracture; sub nodular to sub tabular cuttings; earthy to dull luster; silty to gritty texture; massive or laminae structure; carbonaceous laminations; grainier siltstone is closely transitional to very fine sandstone. Sand (3100'-3120') = medium dark gray to dark gray, slight salt/pepper appearance; upper fine to lower medium; spherical to sub discoidal; sub round to sub angular; well to moderately well sorted; unconsolidated; texturally immature; compositionally immature; quartz, translucent to transparent; moderate reddish brown lithics, grayish green lithics; porosity and permeability visually good. Tuffaceous Siltstone (3120'-3250') = medium gray to medium light gray; easily friable to soft; poorly indurated; crunchy to crumbly tenacity; earthy fracture; sub-nodular to sub-tabular cuttings habit; earthy to dull luster; silty to gritty texture; massive or laminar structure. Sand/Sandstone (3250'-3400') = overall homogeneous appearance; medium gray to medium dark gray with moderate olive gray and faint brownish gray secondary hues; range fine upper to coarse lower; most abundant fraction is medium lower close to fine upper boundary; trace scattering of grains to very coarse upper; dominant mode of angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), but pervasive minor mode of more rounded and spherical grains, and trace to extreme ranges of roundedness and shape; very dominant disaggregated loose grains, but well distributed trace to common consolidated pieces and/or grains with discernible attached cementation; sandstone pieces mostly grain supported with weak siliceous and (lesser) calcite cementation; matrix supported sandstone has more complex intergrain bonding, with clay-silt-ash combinations with the cements; compositional graywacke (>30% lithics) to sublithic arenite; estimate 40-60% quartz, 10-20% various forms of crypto-silica and micro-silica including distinctive chalcedony and jasper, 5-10% feldspar, 20-35% lithics and mafic minerals; note strong contrast of diverse greenstone lithics and grains of red to reddish orange volcanic rock fragments. Sand/Sandstone (3400'-3600') = continued overall homogenous appearance; note sorting is increasingly variable, with some samples moderately well sorted and others with wide range from fine lower to trace granule; grain size characteristics suggest some bi-modal sands and subtle fining upward in thicker sections; medium gray to medium dark gray with moderate olive gray and faint brownish gray secondary hues; range fine lower to very coarse upper and granules; dominant fine upper to medium upper; some siltstone-claystone fragments may be large floating lithic clasts; dominantly angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), and constant minor mode of rounded and spherical grains, with traces to either well rounded or very angular; dominant disaggregated loose grains, but locally abundant to dominant consolidated sandstone fragments and grains with discernible attached cementation; most sandstone grain supported, but friable with weak silica cementation; matrix supported has complex intergrain of tuffaceous clay-silt, devitrified and non-devitrified volcanic ash and variable silica and calcite cementation; compositional graywacke (>30% lithics) to lithic arenite; estimate 40-65% quartz, 10-20% various forms of crypto-silica and micro- silica including distinctive chalcedony and jasper, 5-10% feldspar, 20-35% lithics and mafic minerals; prominent contrast of diverse greenstone lithics and grains of red to reddish orange volcanic lithics. 11 Sand/Sandstone (3600'-3760') = continued fairly homogenous appearance; medium gray to medium dark gray with moderate to strong light olive gray to olive gray secondary hues and faint to locally moderate light brownish gray hues; overall also has slight "dirty" salt and pepper appearance; note that fine red volcanic fragments are discernible with the naked eye; range fine lower to medium upper; moderately well sorted with dominant size medium lower close to fine upper boundary; dominantly angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), and constant minor mode of rounded and spherical grains, with traces to well-rounded or very angular; dominant disaggregated loose grains, but locally very common consolidated sandstone fragments and grains with discernible attached cementation; consolidated pieces are dominantly grain supported, friable to slightly crunchy; abundant weak silica cementation and only spotty calcite cement; matrix support has complex intergrain support consisting of tuffaceous clay-silt, devitrified and non- divitrified volcanic ash and silica/ calcite; compositional graywacke (>30% lithics) to lithic arenite; estimate 40-65% quartz), 10-20% various forms of crypto-silica and micro-silica and other non- differentiated silica, including distinctive chalcedony and jasper, 5-10% feldspar,20-35% lithics and mafic minerals; continued very distinctive contrast of prominent diverse greenstone lithics and grains of red to reddish orange volcanic lithics. Tuffaceous Siltstone/Tuffaceous Claystone (3760'-4100') = prominent overall increase in silt-clay fractions; medium light gray to light grayish brown with faint light olive gray and pale brown secondary hues; many other subtle gray and brown secondary hues and many subtle shifts in lightness value; note a consistent fraction of the claystone after 3940’ that is medium bluish gray with faint greenish gray secondary coloration; soft to slightly firm or slightly brittle; nearly all is hydrophilic and becomes mushy when hydrated; softer clays have poor to moderate cohesiveness and moderate to good adhesiveness; all soft rocks appear either derived or associated with volcanic ash, and often display easily discernible microshards within the rock’s fabric; silty to clayey to ashy to various soft matte, mottled and mixed textures; tuffaceous claystone is closely gradational to less reworked "Cook Inlet" volcanic ash; traces still retain relict pseudo-textures from the original vitric ash; silt-clay-ash are the matrix support of most soft sandstone, and grades to tuffaceous sandstone; note that the variations of the sandstone and siltstone in the cuttings are more suggestive of interbedding than massive bedding; even if adjacent to coals, there very few cuttings pieces that display laminations and/or particles of coal or other types of carbonaceous material. Tuffaceous Sandstone (3860'-4100') = note trace to spotty tuffaceous sandstone, which closely grades to very sandy tuffaceous claystone, and has a distinctly ashier matrix than above, is consistently observed after 3860'; light gray to light medium gray; it generally has the same overall characteristics as all other sandstones, but also has a significant grain size fraction (composed mostly of winnowed glass micro-shards) at very fine lower; some of the larger cuttings pieces have easily discernible fining upward in one direction; note that very common tuffaceous sandstone has soft floating grains of both weathered volcanics and/or weathered greenstones. All Lithologies (4060'-4160') = note that the bulk habit for all undifferentiated rock cuttings is slightly different; cuttings habit is more blocky-punky than irregular, pieces are larger and generally firmer, and there is a wider range of coloration; more pieces are either a secondary or primary bluish gray, greenish gray, light yellowish brown, grayish orange pink or light yellowish gray; calcite cementation of sandstone and siltstone increases from trace to locally common; also note traces of calcareous tuffaceous claystone that are brittle to marginally hard. Tuffaceous Siltstone (4160'-4240') = medium light gray to medium gray; easily friable to soft to friable; poorly to moderately poorly indurated; crumbly to crunchy tenacity; earthy or irregular fracture; massive, bladed or sub tabular cuttings habit; earthy to dull luster; silty to gritty to clayey texture; massive or laminae structure; carbonaceous material imbedded w/in siltstone; siltstone almost becomes lower very fine grained tuffaceous sandstone. 12 Tuffaceous Siltstone (4240'-4340') = medium light gray to medium gray; easily friable to soft; poorly to moderately poorly indurated; crumbly to crunchy tenacity; earthy or irregular fracture; thick bladed or sub-tabular cuttings habit; earthy to dull luster; silty to gritty to clayey texture; massive or laminar structure; carbonaceous material commonly imbedded within the siltstone; associated sand: upper fine to lower fine, spherical, sub-rounded, well sorted, unconsolidated to soft, tuffaceous matrix supported sandstone; translucent and transparent quartz. Tuffaceous Sandstone (4340'-4380') = medium light gray to light gray; lower very fine to upper very fine; spherical to sub-discoidal; rounded to sub-rounded; well sorted; soft to very friable; abundant tuffaceous matrix supported; quartz, transparent to translucent; note black carbonaceous lithic fragments; visual porosity is fair to poor. Tuffaceous Sandstone (4380'-4420') = medium light gray to light gray; lower very fine to upper very fine; spherical to sub discoidal; round to sub round; well sorted; soft to very friable; abundant tuffaceous matrix supported; quartz, transparent to translucent; note black carbonaceous lithic fragments; visual porosity is fair to poor. Tuffaceous Sandstone (4420'-4470') = medium light gray to light gray; lower very fine to upper very fine; spherical to sub-discoidal; rounded to sub-rounded; well sorted; soft to very friable; abundant tuffaceous matrix supported; quartz, transparent to translucent; note black carbonaceous lithic fragments; visual porosity is poor. 3.3 Sampling Program Set Type and Purpose Interval Frequency Distribution A Washed and Dried Reference 2425’ – 4470’ 20’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference 2425’ – 4070’ 20’ Jacob Dunston Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 C Wet, Lightly Rinsed Sieve Analysis 2425’ – 4470’ 20’ James Kvidera Canrig Drilling Technology LTD 301 E 92nd Ave, Suite #2 Anchorage, AK 99515 13 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 105.32 0.17 170.85 105.32 -0.13 0.02 0.06 0.19 170.07 0.19 170.85 170.07 -0.33 0.05 0.15 0.03 229.60 0.22 121.04 229.60 -0.49 0.17 0.15 0.29 292.47 0.31 136.72 292.47 -0.67 0.39 0.08 0.18 359.12 1.13 223.99 359.11 -1.28 0.05 0.71 1.74 421.42 3.83 234.12 421.35 -2.94 -2.06 3.39 4.37 482.88 5.44 233.76 482.61 -5.86 -6.07 8.36 2.62 544.77 8.85 234.88 544.01 -10.34 -12.33 16.05 5.51 605.75 11.13 235.34 604.06 -16.38 -21.01 26.63 3.74 667.69 14.40 236.97 664.46 -23.98 -32.39 40.30 5.31 728.27 16.14 236.72 722.90 -32.71 -45.75 56.24 2.87 790.92 18.98 235.26 782.62 -43.30 -61.40 75.12 4.59 852.59 20.96 234.35 840.58 -55.44 -78.61 96.18 3.25 914.79 24.84 233.47 897.87 -69.71 -98.15 120.38 6.26 976.72 26.50 233.83 953.69 -85.61 -119.76 147.21 2.69 1038.07 28.87 233.91 1008.01 -102.41 -142.78 175.71 3.86 1100.26 31.64 232.96 1061.72 -121.08 -167.94 207.04 4.52 1160.65 31.68 233.24 1113.13 -140.12 -193.29 238.73 0.25 1223.63 31.43 233.48 1166.79 -159.79 -219.73 271.69 0.44 1287.09 31.94 233.50 1220.79 -179.62 -246.52 305.02 0.80 1349.38 32.83 234.08 1273.40 -199.32 -273.44 338.38 1.51 1411.43 32.87 234.59 1325.52 -218.95 -300.79 372.04 0.45 1473.12 32.72 234.17 1377.38 -238.41 -327.95 405.45 0.44 1534.54 32.35 234.44 1429.16 -257.68 -354.78 438.48 0.65 1597.21 31.98 234.92 1482.21 -276.97 -382.00 471.84 0.72 1659.02 31.83 235.09 1534.68 -295.71 -408.76 504.51 0.28 1721.75 32.34 233.48 1587.83 -315.16 -435.81 537.82 1.59 1783.77 32.40 234.29 1640.22 -334.73 -462.63 571.03 0.71 1845.60 32.26 233.62 1692.46 -354.18 -489.37 604.09 0.62 1907.69 32.32 233.33 1744.95 -373.93 -516.02 637.26 0.27 1969.81 32.69 233.54 1797.34 -393.81 -542.83 670.64 0.62 2031.36 32.89 233.72 1849.08 -413.58 -569.67 703.97 0.36 2093.38 32.90 233.50 1901.16 -433.56 -596.79 737.65 0.19 14 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2155.23 33.39 233.71 1952.94 -453.63 -624.01 771.47 0.81 2216.90 33.59 233.80 2004.38 -473.75 -651.45 805.50 0.33 2277.74 32.63 232.39 2055.34 -493.70 -678.03 838.73 2.02 2341.24 32.85 232.43 2108.75 -514.65 -705.24 873.05 0.35 2402.93 31.63 231.47 2160.93 -534.93 -731.16 905.94 2.14 2465.54 31.93 231.30 2214.15 -555.50 -756.92 938.88 0.50 2488.57 32.11 231.19 2233.68 -563.15 -766.45 951.08 0.82 2577.49 30.17 236.26 2309.79 -590.38 -803.45 997.02 3.67 2639.26 28.62 234.34 2363.61 -607.62 -828.38 1027.33 2.94 2701.14 26.62 236.26 2418.44 -623.97 -851.95 1056.00 3.54 2762.92 23.86 236.41 2474.31 -638.57 -873.88 1082.32 4.47 2825.92 22.22 235.91 2532.29 -652.30 -894.36 1106.96 2.62 2888.05 20.15 235.79 2590.21 -664.90 -912.94 1129.40 3.33 2950.08 17.82 236.02 2648.87 -676.21 -929.65 1149.57 3.76 3012.50 15.65 236.63 2708.64 -686.18 -944.60 1167.53 3.49 3074.02 12.74 238.49 2768.27 -694.29 -957.32 1182.58 4.79 3136.83 10.41 237.78 2829.80 -700.94 -968.02 1195.15 3.72 3196.92 7.86 236.52 2889.13 -706.10 -976.04 1204.67 4.26 3259.70 4.79 227.71 2951.52 -710.23 -981.56 1211.57 5.11 3321.32 2.95 250.78 3013.00 -712.49 -984.97 1215.64 3.85 3382.65 0.90 285.22 3074.29 -712.88 -986.92 1217.46 3.69 3444.89 1.07 334.05 3136.52 -712.23 -987.65 1217.66 1.33 3506.80 1.19 337.02 3198.42 -711.12 -988.15 1217.42 0.21 3570.08 0.72 216.95 3261.70 -710.83 -988.65 1217.65 2.64 3631.91 0.69 206.17 3323.52 -711.47 -989.05 1218.35 0.22 3692.52 0.99 209.85 3384.13 -712.26 -989.47 1219.15 0.50 3756.42 0.75 204.72 3448.02 -713.12 -989.92 1220.02 0.39 3818.47 1.01 195.84 3510.06 -714.01 -990.24 1220.81 0.47 3879.05 0.76 212.04 3570.63 -714.87 -990.60 1221.60 0.58 3942.64 0.62 211.40 3634.22 -715.52 -991.00 1222.31 0.22 4004.57 0.78 192.61 3696.14 -716.21 -991.27 1222.93 0.45 4065.99 0.72 205.25 3757.56 -716.97 -991.52 1223.58 0.29 4126.31 0.98 176.67 3817.88 -717.83 -991.65 1224.19 0.81 4189.32 1.00 184.00 3880.87 -718.91 -991.66 1224.84 0.20 4252.79 0.98 202.73 3944.33 -719.97 -991.91 1225.66 0.51 4314.35 1.06 177.06 4005.89 -721.02 -992.08 1226.42 0.75 4376.33 1.07 181.08 4067.86 -722.17 -992.06 1227.08 0.12 4438.14 1.10 178.24 4129.65 -723.34 -992.06 1227.76 0.10 4470.00 1.10 178.24 4161.51 -723.95 -992.04 1228.10 0.00 15 4. 2 B i t R e c o r d BI T NO . SI Z E TY P E S/ N JE T S / TF A IN OU T Fe e t Dr i l l e d HR S AV E RO P (F t / H R ) CONDITION 1 9 7 / 8 ” Va r e l D T 1 G J M R S Tr i c o n e 13 7 9 5 2 7 3x 1 8 / 1 x 1 6 0. 9 4 1 9 12 0 ’ 2 5 2 5 ’ 2 4 0 5 2 0 . 3 3 1 3 5 1 - 1 - W T - A - E - 1 - N O - T D 2 6 . 7 5 ” Va r e l V 5 1 3 P D H R U PD C 40 0 7 8 2 7 4X 9 / 3 X 1 0 0. 4 7 8 6 25 2 5 ’ 4 4 7 0 ’ 1 9 4 5 1 5 . 6 9 1 3 2 1 - 1 - C T - N - X - I - E R - T D 2R R 6 . 7 5 ” Va r e l V 5 1 3 P D H R U PD C 40 0 7 8 2 7 4X 9 / 3 X 1 0 0. 4 7 8 6 44 7 0 ’ 4 4 7 0 ’ 0 C l e a n O u t R u n O n l y 16 4. 3 M u d R e c o r d Co n t r a c t o r : M . I . S w a c o Da t e De p t h MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Cl (ml/l) Ca (ml/l) MD ( f t ) TV D (f t ) Sp u d M u d 9/ 1 0 / 2 0 1 5 1 2 0 1 2 0 8 . 7 0 1 1 2 30 4 0 2 0 / 3 7 / 4 3 8 . 5 2 / 0 2 . 8 0. 0 / 9 7 . 0 - 2 3 . 5 1 0 . 0 3 0 0 - 9/ 1 1 / 2 0 1 5 5 1 0 5 0 9 8 . 8 0 2 2 2 38 5 9 2 2 / 3 6 / 4 3 8 . 5 2 / 0 3 . 5 0. 3 / 9 6 . 0 0. 4 5 2 2 . 5 8 . 9 3 0 0 1 0 9/ 1 2 / 2 0 1 5 2 0 0 6 1 8 2 8 9 . 2 0 1 4 5 38 4 7 1 6 / 3 8 / 4 6 6 . 8 2 / 0 6 . 5 0. 3 / 9 3 . 0 0. 2 5 2 2 . 5 8 . 5 2 0 0 2 0 9/ 1 3 / 2 0 1 5 2 5 2 5 2 2 6 4 9 . 2 0 6 3 32 2 2 6 / 8 / 1 0 6 . 2 1 / 0 6 . 5 0. 3 / 9 3 . 0 0. 2 0 2 0 . 0 7 . 6 2 0 0 2 0 9/ 1 4 / 2 0 1 5 2 0 2 5 2 2 6 4 9 . 2 2 4 6 18 8 3 / 1 0 / 1 7 7 . 5 1 / 0 7 . 5 0. 1 / 9 3 . 0 0. 1 0 1 7 . 5 4 . 3 1 5 0 2 0 6% K C l E Z M u d D P 9/ 1 5 / 2 0 1 5 2 5 4 5 2 2 8 0 8 . 8 8 5 3 8 1 8 7 / 9 / 1 1 5 . 9 1 / 2 1 . 4 0. 0 / 9 6 . 1 - - 9 . 9 3 0 0 0 0 6 0 9/ 1 6 / 2 0 1 5 4 1 6 0 3 8 5 1 8 . 9 0 5 3 12 1 8 6 / 8 / 1 1 4 . 6 1 / 2 1 . 8 0. 1 / 9 5 . 7 - 1 . 3 9 . 2 2 9 5 0 0 8 0 9/ 1 7 / 2 0 1 5 4 4 7 0 4 1 6 2 9 . 1 0 5 4 12 2 1 7 / 9 / 1 1 4 . 4 1 / 2 2 . 7 0. 1 / 9 4 . 6 - 1 . 5 9 . 7 3 1 0 0 0 4 0 9/ 1 8 / 2 0 1 5 4 4 7 0 4 1 6 2 9 . 0 5 5 7 12 1 9 6 / 8 / 1 1 4 . 3 1 / 2 2 . 5 0. 1 / 9 5 . 0 - 1 . 5 1 0 . 3 2 9 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 G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e L o s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l k , P m = A l k a l i n i t y , M u d pH = A c i d i t y C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d 17 4. 4 . D r i l l i n g P r o g r e s s 0 50 0 10 0 0 15 0 0 20 0 0 25 0 0 30 0 0 35 0 0 40 0 0 45 0 0 50 0 0 9 / 9 / 2 0 1 5 9 / 1 0 / 2 0 1 5 9 / 1 1 / 2 0 1 5 9 / 1 2 / 2 0 1 5 9 / 1 3 / 2 0 1 5 9 / 1 4 / 2 0 1 5 9 / 1 5 / 2 0 1 5 9 / 1 6 / 2 0 1 5 9 / 1 7 / 2 0 1 5 9 / 1 8 / 2 0 1 5 9 / 1 9 / 2 0 1 5 9 7/8"Hole 6 3/4"Hole 18 5 SHOW REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 2836'MD 2858'MD Country: 20 2549'TVD 2570'TVD Averages Before During After Maximum ROP (fph) 155 ft/hr 139 ft/hr 114 ft/hr 174 ft/hr WOB 1 klbs 1 klbs 0 klbs 2 klbs RPM 58 rpm 56 rpm 0 rpm 59 rpm PP 1392 psi 1379 psi 1345 psi 1396 psi Mud Weight 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 30,000 30,000 30,000 30,000 Total Gas 216 75 20 137 C1 (ppm) 42,236 14,684 3,851 26,726 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 2:36 AM Residual Cut Sand = dark gray to medium dark gray with overall salt and pepper appearance; upper medium to lower medium to occasionally coarse; spherical to sub-discoidal; sub-angular to sub-rounded; well to moderately well sorted; unconsolidated; texturally immature; quartz, translucent to transparent; orangish red lithics, black lithics, light olive green lithics; porosity visually good. 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 3219'MD 3249'MD Country: 20 2919'TVD 2949'TVD Averages Before During After Maximum ROP (fph) 140 ft/hr 149 ft/hr 141 ft/hr 252 ft/hr WOB 1 klbs 0 klbs 1 klbs 1 klbs RPM 77 rpm 27 rpm 42 rpm 78 rpm PP 1604 psi 1565 psi 1589 psi 1606 psi Mud Weight 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 29,000 29,000 29,000 29,000 Total Gas 166 103 109 230 C1 (ppm) 33,091 20,513 21,461 45,836 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow to sublithic arenite; estimate 40-60% quartz, 10-20% various forms of crypto-silica and micro-silica including distinctive chalcedony and jasper, 5-10% feldspar, 20-35% lithics and mafic minerals; note strong contrast of diverse greenstone lithics and grains of red to reddish orange volcanic rock fragments. GAS SHOW Oil Show Rating Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 8:00 AM Residual Cut Sand/Sandstone = overall homogeneous appearance; m edium gray to medium dark gray with moderate olive gray and faint brownish gray secondary hues; range fine upper to coarse lower; most abundant fraction is medium lower close to fine upper boundary; trace scattering of grains to very coarse upper; dominant mode of angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), but pervasive minor mode of more rounded and spherical grains, and trace to extreme ranges of roundedness and shape; very dominant disaggregated loose grains, but well distributed trace to common consolidated pieces and/or grains with discernible attached cementation; sandstone pieces mostly grain supported with weak siliceous and (lesser) calcite cementation; matrix supported sandstone has more complex intergrain bonding, with clay-silt-ash combinations with the cements; compositional graywacke (>30% lithics) (Continue below) 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 3 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 3356'MD 3374'MD Country: 20 3056'TVD 3074'TVD Averages Before During After Maximum ROP (fph) 137 ft/hr 174 ft/hr 176 ft/hr 262 ft/hr WOB 2 klbs 1 klbs 0 klbs 1 klbs RPM 80 rpm 16 rpm 0 rpm 79 rpm PP 1584 psi 1351 psi 1416 psi 1395 psi Mud Weight 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 29,000 29,000 29,000 29,000 Total Gas 200 72 72 94 C1 (ppm) 40,612 14,681 14,617 19,098 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = overall homogeneous appearance; medium gray to medium dark gray with moderate olive gray and faint brownish gray secondary hues; range fine upper to coarse lower; most abundant fraction is medium lower close to fine upper boundary; trace scattering of grains to very coarse upper; dominant mode of angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), but pervasive minor mode of more rounded and spherical grains, and trace to extreme ranges of roundedness and shape; very dominant disaggregated loose grains, but well distributed trace to common consolidated pieces and/or grains with discernible attached cementation; sandstone pieces mostly grain supported with weak siliceous and (lesser) calcite cementation; matrix supported sandstone has more complex intergrain bonding, with clay-silt-ash combinations with the cements; compositional graywacke (>30% lithics) to (Continue below) Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 11:35 AM Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow sublithic arenite; estimate 40-60% quartz, 10-20% various forms of crypto-silica and micro-silica including distinctive chalcedony and jasper, 5-10% feldspar, 20-35% lithics and mafic minerals; note strong contrast of diverse greenstone lithics and grains of red to reddish orange volcanic rock fragments. GAS SHOW Oil Show Rating 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 4 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 3448'MD 3474'MD Country: 20 3148'TVD 3174'TVD Averages Before During After Maximum ROP (fph) 124 ft/hr 117 ft/hr 132 ft/hr 144 ft/hr WOB 2 klbs 1 klbs 1 klbs 2 klbs RPM 73 rpm 73 rpm 78 rpm 74 rpm PP 1791 psi 1761 psi 1762 psi 1800 psi Mud Weight 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 29,000 29,000 29,000 29,000 Total Gas 141 102 75 155 C1 (ppm) 29,395 22,091 15,458 33,536 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = overall homogenous appearance; note sorting is increasingly variable, with some samples moderately well sorted and others with wide range from fine lower to trace granule; grain size characteristics suggest some bi-modal sands and subtle fining upward in thicker sections; medium gray to medium dark gray with moderate olive gray and faint brownish gray secondary hues; range fine lower to very coarse upper and granules; dominant fine upper to medium upper; some siltstone- claystone fragments may be large floating lithic clasts; dominantly angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), and constant minor mode of rounded and spherical grains, with traces to either well rounded or very angular; dominant disaggregated loose grains, but locally abundant to dominant consolidated sandstone fragments and grains with discernible attached cementation; most sandstone grain (Continued below) Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 1:05 PM Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow supported, but friable with weak silica cementation; matrix supported has complex intergrain of tuffaceous clay-silt, devitrified and non-devitrified volcanic ash and variable silica and calcite cementation; compositional graywacke (>30% lithics) to lithic arenite; estimate 40-65% quartz, 10-20% various forms of crypto-silica and micro-silica including distinctive chalcedony and jasper, 5-10% feldspar, 20-35% lithics and mafic minerals; prominent contrast of diverse greenstone lithics and grains of red to reddish orange volcanic lithics. GAS SHOW Oil Show Rating 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 5 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 3522'MD 3534'MD Country: 20 3222'TVD 3234'TVD Averages Before During After Maximum ROP (fph) 123 ft/hr 114 ft/hr 157 ft/hr 133 ft/hr WOB 1 klbs 1 klbs 0 klbs 1 klbs RPM 79 rpm 80 rpm 20 rpm 81 rpm PP 1822 psi 1822 psi 1794 psi 1836 psi Mud Weight 8..8 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 29,000 29,000 29,000 29,000 Total Gas 162 112 38 163 C1 (ppm) 34,489 22,590 7,666 33,088 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone = overall homogenous appearance; note sorting is increasingly variable, with some samples moderately well sorted and others with wide range from fine lower to trace granule; grain size characteristics suggest some bi-modal sands and subtle fining upward in thicker sections; medium gray to medium dark gray with moderate olive gray and faint brownish gray secondary hues; range fine lower to very coarse upper and granules; dominant fine upper to medium upper; some siltstone- claystone fragments may be large floating lithic clasts; dominantly angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), and constant minor mode of rounded and spherical grains, with traces to either well rounded or very angular; dominant disaggregated loose grains, but locally abundant to dominant consolidated sandstone fragments and grains with discernible attached cementation; most sandstone grain (Continued below) Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 1:50 PM Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow supported, but friable with weak silica cementation; matrix supported has complex intergrain of tuffaceous clay-silt, devitrified and non-devitrified volcanic ash and variable silica and calcite cementation; compositional graywacke (>30% lithics) to lithic arenite; estimate 40-65% quartz, 10-20% various forms of crypto-silica and micro-silica including distinctive chalcedony and jasper, 5-10% feldspar, 20-35% lithics and mafic minerals; prominent contrast of diverse greenstone lithics and grains of red to reddish orange volcanic lithics. GAS SHOW Oil Show Rating 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 6 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 3707'MD 3748'MD Country: 20 3407'TVD 3448'TVD Averages Before During After Maximum ROP (fph) 143 ft/hr 134 ft/hr 152 ft/hr 287 ft/hr WOB 3 klbs 2 klbs 2 klbs 4 klbs RPM 77 rpm 77 rpm 76 rpm 78 rpm PP 1858 psi 1810 psi 1828 psi 1865 psi Mud Weight 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 29,000 29,000 29,000 29,000 Total Gas 272 136 61 564 C1 (ppm) 54,658 27,481 12,256 113,576 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Sand/Sandstone (3600'-3760') = Fairly homogenous appearance; medium gray to medium dark gray with moderate to strong light olive gray to olive gray secondary hues and faint to locally moderate light brownish gray hues; overall also has slight "dirty" salt and pepper appearance; note that fine red volcanic fragments are discernible with the naked eye; range fine lower to medium upper; moderately well sorted with dominant size medium lower close to fine upper boundary; dominantly angular to subangular, subdiscoidal to subspherical, roughly equant to very slightly elongated (prismoidal), and constant minor mode of rounded and spherical grains, with traces to well rounded or very angular; dominant disaggregated loose grains, but locally very common consolidated sandstone fragments and grains with discernible attached cementation; consolidated pieces are dominantly grain supported, friable to slightly crunchy; abundant weak silica cementation and (Continued below) Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 3:50 PM Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow only spotty calcite cement; matrix support has com plex intergrain support consisting of tuffaceous clay- silt, devitrified and non-divitrified volcanic ash and silica/ calcite; compositional graywacke (>30% lithics) to lithic arenite; estimate 40-65% quartz), 10-20% various forms of crypto-silica and micro-silica and other non-differentiated silica, including distinctive chalcedony and jasper, 5-10% feldspar,20-35% lithics and mafic minerals; continued very distinctive contrast of prominent diverse greenstone lithics and grains of red to reddish orange volcanic lithics. GAS SHOW Oil Show Rating 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 7 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 3981'MD 3997'MD Country: 20 3681'TVD 3697'TVD Averages Before During After Maximum ROP (fph) 131 ft/hr 152 ft/hr 148 ft/hr 191 ft/hr WOB 2 klbs 1 klbs 1 klbs 1 klbs RPM 63 rpm 62 rpm 62 rpm 63 rpm PP 1861 psi 1869 psi 1870 psi 1896 psi Mud Weight 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal 8.9 lbs/gal Chloride 29,500 29,500 29,500 29,500 Total Gas 142 365 161 382 C1 (ppm) 29,539 77,185 34,082 80,903 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Tuffaceous Sandstone = note trace to spotty tuffaceous sandstone, which closely grades to very sandy tuffaceous claystone, and has a distinctly ashier m atrix than above, is consistently observed after 3860'; light gray to light medium gray; it generally has the same overall characteristics as all other sandstones, but also has a significant grain size f raction (composed mostly of winnowed glass micro- shards) at very fine lower; some of the larger cuttings pieces have easily discernible fining upward in one direction; note that very common tuffaceous sandstone has soft floating grains of both weathered volcanics and/or weathered greenstones. Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/16/20215 6:50 PM Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow GAS SHOW Oil Show Rating 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 8 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 20 4421'MD 4456'MD Country: 10 4112'TVD 4147'TVD Averages Before During After Maximum ROP (fph) 98 ft/hr 114 ft/hr 101 ft/hr 146 ft/hr WOB 3 klbs 2 klbs 3 klbs 3 klbs RPM 80 rpm 80 rpm 80 rpm 81 rpm PP 1821 psi 1799 psi 1800 psi 1834 psi Mud Weight 9.9 lbs/gal 9.9 lbs/gal 9.9 lbs/gal 9.9 lbs/gal Chloride 29,500 29,500 29,500 29,500 Total Gas 63 173 75 302 C1 (ppm) 12,719 34,606 14,663 61,335 C2 (ppm) - - - - C3 (ppm) - - - - C4 (ppm) - - - - C5 (ppm) - - - - Lithology Odor Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Color Intesity Color Color Comments Report by: Residual Cut Tuffaceous Sandstone = medium light gray to light gray; lower very fine to upper very fine; spherical to sub-discoidal; rounded to sub-rounded; well sorted; soft to very friable; abundant tuffaceous m atrix supported; quartz, transparent to translucent; note black carbonaceous lithic fragments; visual porosity is poor. Stain Hilcorp Alaska, LLC 50-133-20652-00-00 SRU 213-15 Swanson River Unit Saxon 169 9/17/20215 6:50 PM Cut Free Oil in Mud Kenai Borough Alaska USA Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis Craig Silva / Tollef Winslow GAS SHOW Oil Show Rating 1 10 100 1000 10000 100000 1000000 1 2 3 4 pp m Pixler Plot DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 19 6 DAILY REPORTS Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Rance Pederson / Shane Barber DATE Sept 10, 2015 DEPTH 120' PRESENT OPERATION Rigging up TIME 24:00:00 YESTERDAY 120' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 8.7 VIS 112 PV 30 YP 40 FL 8.5 Gels 20/37/43 CL- 300 FC 2/0 SOL 2.8 SD - OIL 0.0/97.0 MBT 23.5 pH 10.0 Ca+ - Alk 0.20 MWD SUMMARY INTERVAL TO TOOLS None GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY No Lithology PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY The rig continued to prepare to drill: the rig was assembled and spud mud was built. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2025 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Rance Pederson / Shane Barber DATE Sep 11, 2015 DEPTH 639' PRESENT OPERATION Drilling Ahead TIME 24:00:0 YESTERDAY 120' 24 HOUR FOOTAGE 519' CASING INFORMATION 13 3/8" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 421.42' 3.83 234.12 421.35' 482.88' 5.64 233.76 482.60' 544.77' 8.85 234.88 543.99' 605.75' 11.13 235.34 604.04' 667.69' 14.40 236.97 664.44' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 9 7/8" Varle DT1GJMRS (Tri Cone) 1379527 3x18, 1x16 120' 519' 4.37 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 460.1 @ 535' 3.6 @ 211' 127.0 24.44 FT/HR SURFACE TORQUE 21018 @ 215' 1258 @ 546' 5438.3 0.00 FT-LBS WEIGHT ON BIT 16 @ 266' 0 @ 371' 5.6 8.35 KLBS ROTARY RPM 63 @ 270' 4 @ 546' 33.8 0.00 RPM PUMP PRESSURE 1269 @ 615' 500 @ 127' 1026.1 1199.34 PSI DRILLING MUD REPORT DEPTH 510' MD / 509' TVD MW 8.80 VIS 222 PV 38 YP 59 FL 8.5 Gels 22/36/43 CL- 300 FC 2/0 SOL 3.5 SD 0.45 OIL 0.3/96.0 MBT 22.5 pH 8.9 Ca+ 10 Alk 0.10 MWD SUMMARY INTERVAL 120' TO 639' TOOLS Gamma, Resistivity, Pressure While Drilling, Inclination and Azimuth GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 8 @ 534' 0 @ 124' 1.1 TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 2334 @ 534' 22 @ 124' 236.6 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3 / 2 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Surface Deposits PRESENT LITHOLOGY Clay, sand, silt, gravel, and coal. DAILY ACTIVITY SUMMARY The rig finished installing all equipment. The rig was accepted by Hilcorp representative at 02:30. The rig picked up and racked back in the derrick 2300’ of 4 ½” drill pipe. A safety meeting was held with Hilcorp and the Bureau of Land Management. The rig picked up four more stands (eight joints) of 4 ½” drill pipe and racked it back. The rig also picked up eight stands of 4 ½” heavy weight drill pipe and racked it back. The rig made up the bit and motor. The motor bend was changed and the motor was scribed. The logging while drilling and measurement while drilling tools were picked up and programmed. The well was spudded at 13:58. The rig drilled ahead, rotating and sliding, from 120’ to 639’ as of report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2295 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Rance Pederson / Shane Barber DATE Sep 12, 2015 DEPTH 2114' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 639' 24 HOUR FOOTAGE 1475' CASING INFORMATION 13 3/8" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1845.60' 32.26 233.62 1692.46' 1907.69' 32.32 233.33 1744.95' 1969.81' 32.69 233.54 1797.34' 2031.36' 32.89 233.72 1849.08' 2093.38' 32.90 233.50 1901.16' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 9 7/8" Varel DJ1GJMRS (Tri Cone) 1379527 3x18, 1x16 120' 1994' 17.35 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 438.2 @ 1092' 9.4 @ 1944' 134.6 123.44 FT/HR SURFACE TORQUE 20209 @ 1336' 220 @ 710' 5900.0 5604.83 FT-LBS WEIGHT ON BIT 17 @ 1098' 0 @ 1199' 8.4 8.30 KLBS ROTARY RPM 82 @ 1937' 1 @ 909' 59.4 80.40 RPM PUMP PRESSURE 1975 @ 1949' 1027 @ 1222' 1685.7 1957.09 PSI DRILLING MUD REPORT DEPTH 2006' MD / 1828' TVD MW 9.20 VIS 145 PV 38 YP 47 FL 6.8 Gels 16/38/46 CL- 200 FC 2/0 SOL 6.5 SD 0.25 OIL 0.3/93.0 MBT 22.5 pH 8.5 Ca+ 20 Alk - MWD SUMMARY INTERVAL 120' TO 2114' TOOLS Gamma, Resistivity, Pressure While Drilling, Inclination and Azimuth GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 123 @ 1674' 0 @ 765' 40.1 TRIP GAS NA CUTTING GAS @ @ WIPER GAS 21u @ 1200', 45u @ 1880' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 24770 @ 1674' 38 @ 765' 8075.7 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 35 / 30 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY Sand, Claystone, Siltstone and Coal. DAILY ACTIVITY SUMMARY Drill ahead, sliding and rotating from 639’ to 1196’. A wiper trip was performed to clean the hole from 1196’ to 200’. Tight spots were encountered at 900’, 839’, 715’, 670’, 594’, 535’ and from 460’ to 320’. There was a maximum overpull during the wiper trip of 20K. These tight spots were either in clay or coal formations. The rig ran back in the hole on elevators, however it was necessary to wash and ream from 720’ to 903’ and from 1070’ to 1200’. 21 units of wiper gas were observed upon returning to bottom. The rig drilled ahead, sliding and rotating from 1200’ to 1255’ and then performed a high viscosity sweep which yielded a 25% increase in cuttings. The rig continued to drill rotating and sliding as per the directional driller from 1255’to 1880’. A high viscosity sweep was pumped which yielded a 50% increase in cuttings when it returned to surface. A wiper trip was performed from 1880’ to 1257’ with no noted tight spots. The rig ran the bit back to bottom (1880’) and began to drill ahead. 45 units of wiper gas were observed. The rig drilled ahead, rotating and sliding, from 1880’ to 2114’ as of report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2295 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Rance Pederson / Shane Barber DATE Sep 13, 2015 DEPTH 2525' PRESENT OPERATION Running 7 5/8" Casing TIME 24:00:00 YESTERDAY 2114' 24 HOUR FOOTAGE 411' CASING INFORMATION 13 3/8" @ 120' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2277.74' 32.63 232.39 2055.34' 2341.24' 32.85 232.43 2108.75' 2402.93' 31.63 231.47 2160.93' 2465.54' 31.93 231.30 2214.15' 2488.57' 32.11 231.19 2233.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 9 7/8" Varel DJ1GJMRS (Tri Cone) 1379527 3x18, 1x16 120' 2525' 2405' 20.33 1-1-WT-A-E-1-NO-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 568.9 @ 2261' 17.8 @ 2254' 147.1 111.05 FT/HR SURFACE TORQUE 5823 @ 2192' 5303 @ 2437' 5128.6 5432.14 FT-LBS WEIGHT ON BIT 23 @ 2245' 2 @ 2255' 8.1 4.09 KLBS ROTARY RPM 82 @ 2513' 72 @ 2398' 72.4 79.20 RPM PUMP PRESSURE 2071 @ 2184' 1918 @ 2130' 1973.7 1941.95 PSI DRILLING MUD REPORT DEPTH 2525' MD / 2264' TVD MW 9.20 VIS 63 PV 32 YP 22 FL 6.2 Gels 6/8/10 CL- 200 FC 1/0 SOL 6.5 SD 0.20 OIL 0.3/93.0 MBT 20 pH 7.6 Ca+ 20 Alk - MWD SUMMARY INTERVAL 120' TO 2525' TOOLS Gamma, Resistivity, Pressure While Drilling, Inclination and Azimuth. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 56 @ 2137' 12 @ 2315' 30.1 TRIP GAS 8 u @ 1900' CUTTING GAS @ @ WIPER GAS 43 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 12980 @ 2137' 2479 @ 2315' 6057.5 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY Sandstone DAILY ACTIVITY SUMMARY Drill ahead rotating and sliding from 2114’ MD to 2520’ MD. Bottom of 9 7/8” hole section in sandstone. Circulate bottoms up and pump around high vis sweep. The sweep came back with minimal increase in cuttings. It was decided to drill another five feet to 2520’ MD. Circulated bottoms up. Pull out of hole on wiper trip from 2525’ MD to 200’ MD. No tight spots observed. Run back in hole from 200’ to apparent tight zone at 990’. Wash and ream from 990’ to 1005’. Continue running in hole on elevators from 1005’ to 2439’. Wash and ream from 2439’ to bottom at 2525’. Circulate bottoms up and pump around Hi-Vis sweep. Observed 43 units of wiper gas. Continue to circulate and condition hole. No increase in cuttings was observed. A flow check was performed and the well was static. Pull out of the hole to from 2525’ to 270’. Break and lay down jars and flex collars. Plug in and download MWD recorded data. Break and lay down remaining BHA. Drain motor. Break bit. Lay down motor and bit. Pull wear bushing. Flush well head. Pick up landing joint and check well head depth. Hold safety meeting with casing crew. Begin rig up. The elevators and elevator links were changed out in preparation for running 7 5/8” casing. Weatherford power tools and slips were rigged up. The rig floor was prepped for casing running. 7 5/8” casing was run in the hole. At report time there was 2267’ of casing in the hole. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2295 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Rance Pederson / Shane Barber DATE Sep 14, 2015 DEPTH 2525' PRESENT OPERATION Testing BOPs TIME 24:00:00 YESTERDAY 2525' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8" @ 142' 7 5/8" @ 2520' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2277.74' 32.63 232.39 2055.34' 2341.24' 32.85 232.43 2108.75' 2402.93' 31.63 231.47 2160.35' 2465.54' 31.93 231.30 2214.15' 2488.57' 32.11 231.19 2233.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED No Bit in the Hole 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 MUD REPORT DEPTH 2525' MD / 2264' MD MW 9.22 VIS 46 PV 18 YP 8 FL 7.5 Gels 3/10/17 CL- 150 FC 1/0 SOL 6.7 SD 0.10 OIL 0.1/93.0 MBT 17.5 pH 4.3 Ca+ 20 Alk - MWD SUMMARY INTERVAL TO TOOLS No tools in the hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 6 u @ 2495' 9u @ 2520' CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY No new lithology DAILY ACTIVITY SUMMARY Continue to run 7 5/8” casing from 2267’ to 2495’. Circulate bottoms up and continue circulating while changing out to long bails. Record 6 units of trip gas. Rig down all Weatherford casing running equipment. Hold pre job meeting with all hands on safety and procedures for cement job. Pick up the hanger and landing joint and land the casing at 2520’. Continue to circulate and condition drilling fluid in preparation for cementing the casing. Record 9 units of trip gas. Rig up cementing head and all other Schlumberger cementing equipment. Switch over to Schlumberger pumping unit. Pump 15 bbls of water and pressure test cementing lines to 1200psi low / 5000psi high. Pump 36 barrels of 10.0 pound per gallon (ppg) mud push. Drop bottom plug. Pump 157.0 bbls of 12.0 ppg lead cement, and follow with 43.0 bbls of 15.4 ppg tail cement. Drop top plug. Displace with initial 10.0 bbls of water and follow with 112.0 bbls of 9.2 ppg spud mud. Bump plug with 1250psi, hold for 3 minutes and then bleed off 0.5 bbls. Cement in place at 04:52 Hrs. Rig down all Schlumberger cementing equipment. Back out landing joint. Install pack-off. Lay down landing joint, casing elevators, and long bails. Rig down flow line and hole fill line. Nipple down and lay out riser. Nipple down DSA spool. Install well head. Install test plug. Pressure test well head to 500psi for 5 minutes and 5000psi for 15 minutes. Pick up and set spacer spool. Finish installing spacer spool and pick and set BOPE. Install kill and HCR lines. Hook up accumulator lines. Charge accumulator and BOP stack. Fill BOP stack and choke manifold. The BOPs were tested. The State of Alaska witness of the BOP test was waived by Jim Regg while the Burea of Land Management choose to witness the BOP tests. The BOP tests were continuing as of report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2295 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Shane Hauck / Shane Barber DATE Sep 15, 2015 DEPTH 2622' PRESENT OPERATION Drilling Ahead TIME 24:00:00 YESTERDAY 2525' 24 HOUR FOOTAGE 97' CASING INFORMATION 13 3/8" @ 142' 7 5/8" @ 2520' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2341.24' 32.85 232.43 2108.75' 2402.93' 31.63 231.47 2160.93' 2465.54' 31.93 231.30 2214.15' 2488.57' 32.11 231.19 2233.68' 2577.49' 30.17 236.26 2309.79' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6.75" Varel V513PDHRU (PDC) 4007827 4x9, 3x10 2525' 97' 2.79 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 200.4 @ 2605' 22.8 @ 2527' 124.4 152.64 FT/HR SURFACE TORQUE 6132 @ 2597' 5432 @ 2525' 4370.0 0.00 FT-LBS WEIGHT ON BIT 4 @ 2547' 0 @ 2527' 1.5 2.38 KLBS ROTARY RPM 79 @ 2525' 40 @ 2542' 30.3 0.00 RPM PUMP PRESSURE 1941 @ 2525' 1275 @ 2527' 1345.6 1315.19 PSI DRILLING MUD REPORT DEPTH 2545' MD / 2820' TVD MW 8.85 VIS 53 PV 8 YP 18 FL 5.9 Gels 7/9/11 CL- 30000 FC 1/2 SOL 1.4 SD - OIL 0.0/96.1 MBT - pH 9.9 Ca+ 60 Alk 0.30 MWD SUMMARY INTERVAL 2525' TO 2622' TOOLS Gamma, Resistivity, Porosity, Density, Sonic, Pressure While Drilling, Inclination and Azimuth. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 36 @ 2525' 7 @ 2546' 18.3 TRIP GAS NA CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7622 @ 2525.00000 1461 @ 2546' 3703.8 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 15 / 18 PENTANE (C-5) @ @ HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Sterling Formation PRESENT LITHOLOGY Sand, Siltstone, Claystone, and Coal. DAILY ACTIVITY SUMMARY ontinue and complete testing of all BOPE. [Test Sequence: #1 – annular/Hydril (test failed); #1 retest - annular/Hydril to 250psi Low / 2500psi High for 10 minutes (pass test); note all other BOPE testing to 250psi Low / 3500psi High for 10 minutes; #2 - upper pipe rams, CMVs 1-3-5-7, mez. kill valve, dart valve (test failed, > cycle and grease mez. kill valve, change out valve on test manifold, ); #2 re-test - upper pipe rams, CMVs 1-3-5-7, mez. kill valve, dart valve (pass test); #3 – CMVs 2-6-8, kill HCR, TIW valve (TIW valve failed); #3 retest – CMVs 2-6-8, kill HCR (pass test); #4 – CMVs 9-11-13, inside kill (CMV 11 failed, > cycle and grease valve); #4 retest – CMVs 9-11-13, inside kill (pass test); #5 – choke, HCR, lower TIW valve on TDS; #6 – inside choke valve; #7 – electric power choke; #8 – manual choke; #9 – lower pipe rams; perform accumulator drawdown test (1450psi and 92 second recovery starting with 3100psi, > four-bottle avg. of 2650psi); #10 – blind rams, CMVs 10-12]. Level rig. Strap 66 joints of 4 ½” drill pipe and 2 joints of 4 ½” HWDP. Set flow nipple. Pick up and make up bit and motor. Scribe motor. Pick and make up remaining directional bottom hole assembly. Uplink to MWD collar and pulse test tools. Load nuclear sources. Pick up and make up flex collars. Continue running in hole with BHA to 812’. Pick up 14 joints of 4 ½” drill pipe and rack 7 stands back. Continue running in hole from 812’, singling in 52 joints of 4 ½” drill pipe to 2400’. Break circulation. Condition mud and circulate surface to surface volume. Wash to 2413’ and stop circulating. Rig up and pressure test casing to 3200psi for 30 minutes. Drill out cement and shoe tract from 2413’ to 2430’. Drill out float equipment. Drill ahead from 2525’ to 2545’ (20’ of new hole) to perform leak off test. Displace spud mud with KCl mud. Rig up and perform leak off test to 11.5 lb/gal EMW. Drill ahead, rotating and sliding, from 2545’ to 2622’ as of midnight. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3425 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Shane Hauck / Shane Barber DATE Sep 16, 2015 DEPTH 4222' PRESENT OPERATION Drilling ahead TIME 24:00:00 YESTERDAY 2622' 24 HOUR FOOTAGE 1600' CASING INFORMATION 13 3/8" @ 142' 7 5/8" @ 2520' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3942.64' 0.62 192.61 3696.14' 4004.57' 0.78 205.25 3757.56' 4065.99' 0.72 176.67 3817.88' 4126.31' 0.98 176.67 3880.87' 4189.32' 1.00 184.00 3944.33' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 3/4" Varel V513PDHRU (PDC) 4007827 4x9 , 3x10 2525' 1697' 14.87 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 376.5 @ 3914' 6.5 @ 3664' 135.8 25.70 FT/HR SURFACE TORQUE 9211 @ 3631' 5252 @ 3610' 5450.0 7978.46 FT-LBS WEIGHT ON BIT 5 @ 4154' 0 @ 3390' 1.5 3.99 KLBS ROTARY RPM 80 @ 3334' 41 @ 2902' 56.3 77.11 RPM PUMP PRESSURE 1978 @ 3863' 1287 @ 2734' 1622.0 1702.53 PSI DRILLING MUD REPORT DEPTH 4160' MD / 3851' TVD MW 8.90 VIS 53 PV 12 YP 18 FL 4.6 Gels 6/8/11 CL- 29500 FC 1/2 SOL 1.8 SD - OIL 0.1/95.7 MBT - pH 9.2 Ca+ 80 Alk 0.25 MWD SUMMARY INTERVAL 2525' TO 4222' TOOLS Gamma, resistivity, Porosity, Density, Sonic, Pressure While Drilling, Inclination and Azimuth. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 564 @ 3710' 7 @ 2752' 99.0 TRIP GAS NA CUTTING GAS @ @ WIPER GAS 82u @ 3352', 79 u @ 4159' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 113576 @ 3710.00000 1498 @ 2624.00000 20094.5 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 60 / 100 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Beluga Formation PRESENT LITHOLOGY Sand, Sandstone, Tuffaceous Siltstone, Tuffaceous Claystone, and Coal. DAILY ACTIVITY SUMMARY The rig drilled from 2622’ to 3352’ with the following parameters: pick up weight – 78 K-lbs – 79 K-lbs, slack off weight -54 K-lbs, rotating at 60 to 62 rpm, top drive torque of 5 K ft-lbs to 6 K ft-lbs, weight on bit of K-lbs stand pipe pressure of 1501 psi and flow in of 325 gpm. A wiper trip was performed from 3352’ to 2514’, no tight spots were encountered. The rig tripped back in the hole from 2514’ to 3352’, washing the last stand down. No fill was encountered in the hole. 88 units of wiper gas were observed. The rig drilled from 3352’ to 3385’ with the following parameters: weight on bit – 3 K-lbs, stand pipe pressure 1600 psi, differential pressure – 40 psi and top drive torque of 5560. The rig continued drilling from 3385’ to 4027’ with the following parameters: weight on bit – 4 K-lbs, stand pipe pressure 1867 psi, differential pressure – 55 psi and top drive torque of 8.8 K ft-lbs. A high vis sweep was pumped at 3430’ with a 50% increase in cuttings. The sweep returned on time. The rig continued to drill from 4027’ to 4159’ with the following parameters: pick up weight - 100 K-lbs, slack off weight - 62 K-lbs, rotating weight - 80 K-lbs, top drive torque 8400 ft-lbs, stand pipe pressure 1641 psi and a flow in of 322 gallons per minute. The rig circulated bottoms up twice and monitored the well for losses. The well dropped 18” in 15 minutes for a 0.2 barrel loss. The rig performed a wiper grip from 4159’ to 3293’ with no tight spots. The well took 1.76 barrels during the trip out. The rig ran back in the hole from 3293’ to 4159’ and found two feet of fill on bottom. The hole took 4.00 barrels during the trip in. The rig pumped two complete bottoms up with a trip gas of 79 units. The rig drilled from 4159’ to 4222’ as of midnight with the following parameters: pick up weight – 100K-lbs, slack off weight - 62 K-lbs, rotating weight – 79 K-lbs, top drive troque – 8 K-lbs and weight on bit between 2 K-lbs and 3 K-lbs . CANRIG PERSONNEL ON BOARD 4 DAILY COST $3425 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Shane Hauck / Shane Barber DATE Sep 17, 2015 DEPTH 4470' PRESENT OPERATION Wireline Operations TIME 24:00:00 YESTERDAY 4222' 24 HOUR FOOTAGE 248' CASING INFORMATION 13 3/8" @ 142' 7 5/8" @ 2520' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4252.79' 0.98 202.73 3944.33' 4314.35' 1.06 177.06 4005.89' 4376.33' 1.07 181.08 4067.86' 4438.14' 1.10 178.24 4129.65' 4470.00' 1.10 178.24 4161.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6 3/4" Varel V513PDHRU (PDC) 4007827 4x9, 3x10 2525' 4470' 1945' 15.69 1-1-CT-N-X-I-ER-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 310.9 @ 4319' 2.4 @ 4408' 114.4 90.86 FT/HR SURFACE TORQUE 8036 @ 4254' 7491 @ 4469' 7818.5 7596.10 FT-LBS WEIGHT ON BIT 5 @ 4262' 1 @ 4229' 2.9 3.80 KLBS ROTARY RPM 81 @ 4409' 72 @ 4288' 78.6 80.20 RPM PUMP PRESSURE 1946 @ 4420' 1700 @ 4284' 1793.8 1821.43 PSI DRILLING MUD REPORT DEPTH 4470' MD / 4162' TVD MW 9.10 VIS 54 PV 12 YP 21 FL 4.4 Gels 7/9/11 CL- 31000 FC 1/2 SOL 2.7 SD - OIL 0.1/94.6 MBT 1.5 pH 9.7 Ca+ 40 Alk 0.25 MWD SUMMARY INTERVAL 2525' TO 4470' TOOLS Gamma, Resistivity, Porosity, Density, Sonic, Pressure While Drilling, Inclination and Azimuth. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 309 @ 4254' 41 @ 4409.00000 114.5 TRIP GAS NA CUTTING GAS @ 0 @ 4470.00000 0.0 WIPER GAS 41 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 61742 @ 4254' 8512 @ 4409' 22799.3 CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Beluga Formation PRESENT LITHOLOGY Sand, Tuffaceous Sandstone, Tuffaceous Siltstone, Tuffaceous Claystone, and Coal. DAILY ACTIVITY SUMMARY The rig drilled ahead from 4222’ to 4470’ with the following parameters: pick up weight – 106 k-lbs, slack off weight 64 k-lbs, rotating weight – 80 k- lbs, top drive torque 7.8 k ft-lbs, stand pipe pressure - 1780 psi, mud pump rate – 327 gallons per minute and top drive speed – 80 rpm. The well was finished at 4470’ MD. Bottoms up was circulated and then the well was monitored which resulted in an 18” fluid drop in 15 minutes for a total of 0.2 barrels lost to the formation. The rig performed a wiper trip from 4470’ to 2484’ (surface casing shoe). During the wiper trip the hole took and extra 6.16 barrels over theoretical displacement. The rig was serviced and the well was monitored with a loss rate of one barrel per hour. At seven am the well was continued to be monitored for the next 30 minutes during which time the well was static. The rig tripped back in the hole from 2484’ to 4470’ Bottoms up was circulated with 41 units of wiper trip gas. A high viscosity sweep was pumped which returned on time with a 25% increase in cuttings. The rig spotted a 23 barrel loss circulation material pill on bottom. A flow check was performed and the well was found to be static. The rig pulled the bit out of the hole from 4470’ to 2235’ with no overpull. A flow check was performed at 2475’ during the trip and the well was found to be static. The rig continued to pull the bit out of the hole form 2235’ to 200’ at which time a flow check was again performed and the well was found to be static. The bottom hole assembly was laid down, the source was pulled and the logging while drilling memory data was downloaded. The overall drilling fluid losses to the formation during the trip were 6.47 barrels. The wireline crew held a safety meeting with the crew to prepare to run wireline in the hole. The wireline truck was spotted, the shives were rigged up and the wireline was rigged up. The RFT logging tools were run in the hole. At report time wireline operations were ongoing. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3425 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Shane Hauck / Shane Barber DATE Sep 18, 2015 DEPTH 4470' PRESENT OPERATION Running 4 1/2" casing at 1331' TIME 24:00:00 YESTERDAY 4470' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8" @ 142' 7 5/8" @ 2520' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4470' 1.10 178.24 4161.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2RR 6 3/4" Varel V513PDHRU (PDC) 4007827 4x9, 3x10 4470' 4470' 0' Not Graded Clean Out Run 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 MUD REPORT DEPTH 4470' MD / 4161' TVD MW 9.05 VIS 57 PV 12 YP 19 FL 4.3 Gels 6/8/11 CL- 29000 FC 1/2 SOL 2.5 SD - OIL 0.1/95.0 MBT 1.5 pH 10.3 Ca+ 40 Alk 0.30 MWD SUMMARY INTERVAL TO TOOLS No tools in the hole GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 91 CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Beluga Formation PRESENT LITHOLOGY Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Continue logging and complete logging program (perform 36 test point attempts from 4342’ to 2790’ and log 28 successful tests). Pull out of hole with XPT tool assembly. (Total mud losses during wireline operations 4.79 bbls). Pull, break and lay down logging tools and rig down all SWS wireline running equipment. Pick up/make up clean-out assembly. Run in hole with clean-out assembly to to bottom at 4461’. Wash down last 9’ of fill to bottom at 4470’. Circulate bottoms up. Record 91 units of trip gas. Continue circulating. Rig generator, and Pason and Pitbull monitoring systems all went down. Continue circulating while troubleshooting system failures. Regain functioning of generator set and monitoring systems. Pump around a 17 bbl Hi-Vis sweep and observe 10% increase in cuttings on return. Circulate and clean hole. Pull out of hole from 4470’ laying down 4 ½” drill pipe. Continue to surface laying down clean-out BHA. No overpull on way out of hole. Hole took 9.28 bbls over theoretical. Clean and prep rig floor for running casing. Flush BOPs and wellhead. Drain stack. Pull wear ring. Prep landing joint perform a dummy run. Rig up all Weatherford casing running equipment. Make up and run-in shoe track. Test floats. Run 4 ½” casing in the hole as per Hilcorp from surface to 1331’. Circulate bottoms up with the following parameters: standpipe pressure – 105 psi, a flow in of 134 gallons per minute and a mud weight of 9.1. No trip gas was observed. CANRIG PERSONNEL ON BOARD 2 DAILY COST $3155 REPORT BY Tollef Winslow Hilcorp Alaska, LLC Swanson River Unit DAILY WELLSITE REPORT SRU 213-15 REPORT FOR Shane Hauck / Shane Barber DATE Sep 19, 2015 DEPTH 4470' PRESENT OPERATION Well cemented, Canrig rigged down.. TIME 24:00:00 YESTERDAY 4470' 24 HOUR FOOTAGE 0' CASING INFORMATION 13 3/8" @ 142' 7 5/8" @ 2520' 4 1/2" @ SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4470' 1.10 178.24 4161.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT-LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk MWD SUMMARY INTERVAL TO TOOLS No tools in the hole GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 29 CUTTING GAS @ @ WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C-1) @ @ CONNECTION GAS HIGH NA ETHANE (C-2) @ @ AVG NA PROPANE (C-3) @ @ CURRENT NA BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 / 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY Upper Beluga Formation PRESENT LITHOLOGY Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Continue running 4 ½” casing from 1331’ to 2455’. Circulate out and observe 4 units of stage gas. Continue running 4 ½” casing in the hole from 2455’ to 3729’. Circulate out (with parameters: standpipe pressure 285 psi, flow in 235 gpm, MW 9.1). 29 units of stage gas were observed. Continue running 4 ½” casing from 3729’ to 4445’ Observe 7.0 bbl loss for entire casing run. Circulate bottoms up (with parameters: pick up weight 54 k-lbs, slack off weight 40 k-lbs, standpipe pressure 329 psi, flow in 234 gpm, MW 9.1). Record 29 units of trip gas. Make up hanger and landing joint. Continue circulating . Rig down Weatherford elevators and pull bushings. Run in with hanger and slack off. Land 4 ½” production casing with 18K string weight. (Shoe at 4465.56’MD). Work pipe and circulate. Rig up Schlumberger cementing equipment and tools while continuing to circulate and work pipe. Prep cementing head with plugs. Hold pre-job meeting with all involved hands on safety and procedures for cement job. Test cement lines to 1000psi low and 5000psi high. Bleed off pressure to cementing unit. Pump 20 bbls of 12.5 ppg Mud Push II with rig pumps. Switch over and line up to Schlumberger pumping unit. Drop bottom plug and pump 51.6 bbls of 13.5 ppg lead cement (with 1 lb/bbl Cemnet added) and follow with 36.0 bbls 15.3 ppg tail cement. Pump 10 bbls water to flush lines to pits. Drop top plug and displace with 66.7 bbls of 8.5 ppg 3% KCL brine. Land hanger with 5 bbls to go and set down with 39K. Bump plug at 66.0 bbls into displacement (0.7 bbls early). Hold 500 psi over for 5 minutes. Bleed off pressure and check floats. Cement In Place at 09:31 hrs on 9-19-2015. Lost 15.0 bbls during displacement (90% returns). Wash through cement lines and rig down Schlumberger cementing equipment. Set pack-off tool and then perform successful test for 5 minutes at 5000 psi. Install back pressure valve in well head. Nipple down all BOPE equipment, nipple up tree and continue all Hilcorp-directed procedures for rig-down and preparation for move to next well at the same SRU 32-15 Pad location. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2295 REPORT BY Tollef Winslow Company Hilcorp Alaska LLC Well Name Swanson River Unit 213-15 Field Name Swanson River Unit Field Location 2158 FNL & 1041 FWL At Surface UWID 50133206520000 Engineer's Name Josh Schultz Date 18-Sep-2015 Report Date 09-20-2015 Prepared By Josh Schultz Job Number 1A Run Number 1A PressureXpress Field Acquisition Report Innovations in Formation Testing InSitu Pro* 2015.1.0 * Mark of Schlumberger 2015-09-20 1 1 WELL AND JOB DATA ......................................................................................................................................................... 5 1.1 WELL SURVEY TABLE ................................................................................................................................................................... 5 2 TEST POINT TABLE ............................................................................................................................................................. 8 3 STATIONS ........................................................................................................................................................................ 12 3.1 CONPR_R01_STA001_XPT 3994.02 FT MD .............................................................................................................................. 12 3.1.1 Pressure vs. Time Plot .................................................................................................................................................... 12 3.1.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 13 3.2 CONPR_R01_STA003_XPT 3982.38 FT MD .............................................................................................................................. 14 3.2.1 Pressure vs. Time Plot .................................................................................................................................................... 14 3.2.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 15 3.3 CONPR_R01_STA004_XPT 3740.01 FT MD .............................................................................................................................. 16 3.3.1 Pressure vs. Time Plot .................................................................................................................................................... 16 3.3.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 17 3.4 CONPR_R01_STA007_XPT 3706.05 FT MD .............................................................................................................................. 18 3.4.1 Pressure vs. Time Plot .................................................................................................................................................... 18 3.4.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 19 3.5 CONPR_R01_STA008_XPT 3689.99 FT MD .............................................................................................................................. 20 3.5.1 Pressure vs. Time Plot .................................................................................................................................................... 20 3.5.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 21 3.6 CONPR_R01_STA009_XPT 3555 FT MD ................................................................................................................................... 22 3.6.1 Pressure vs. Time Plot .................................................................................................................................................... 22 3.6.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 23 3.7 CONPR_R01_STA017_XPT 3470.52 FT MD .............................................................................................................................. 24 3.7.1 Pressure vs. Time Plot .................................................................................................................................................... 24 3.7.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 25 3.8 CONPR_R01_STA018_XPT 3460.02 FT MD .............................................................................................................................. 26 3.8.1 Pressure vs. Time Plot .................................................................................................................................................... 26 3.8.2 FRID, Spherical and Radial Specialized Plots .................................................................................................................. 27 3.9 CONPR_R01_STA019_XPT 3452.01 FT MD .............................................................................................................................. 28 3.9.1 Pressure vs. Time Plot .................................................................................................................................................... 28 3.10 CONPR_R01_STA020_XPT 3454 FT MD ................................................................................................................................ 29 3.10.1 Pressure vs. Time Plot ................................................................................................................................................. 29 3.10.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 30 3.11 CONPR_R01_STA021_XPT 3448.01 FT MD ........................................................................................................................... 31 3.11.1 Pressure vs. Time Plot ................................................................................................................................................. 31 3.11.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 32 3.12 CONPR_R01_STA022_XPT 3379.94 FT MD ........................................................................................................................... 33 3.12.1 Pressure vs. Time Plot ................................................................................................................................................. 33 3.12.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 34 3.13 CONPR_R01_STA023_XPT 3365.99 FT MD ........................................................................................................................... 35 3.13.1 Pressure vs. Time Plot ................................................................................................................................................. 35 3.13.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 36 3.14 CONPR_R01_STA024_XPT 3356.98 FT MD ........................................................................................................................... 37 3.14.1 Pressure vs. Time Plot ................................................................................................................................................. 37 3.14.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 38 3.15 CONPR_R01_STA028_XPT 3265 FT MD ................................................................................................................................ 39 3.15.1 Pressure vs. Time Plot ................................................................................................................................................. 39 3.15.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 40 3.16 CONPR_R01_STA029_XPT 3246.98 FT MD ........................................................................................................................... 41 3.16.1 Pressure vs. Time Plot ................................................................................................................................................. 41 3.16.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 42 3.17 CONPR_R01_STA030_XPT 3234.97 FT MD ........................................................................................................................... 43 3.17.1 Pressure vs. Time Plot ................................................................................................................................................. 43 3.17.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 44 3.18 CONPR_R01_STA032_XPT 3225.96 FT MD ........................................................................................................................... 45 3.18.1 Pressure vs. Time Plot ................................................................................................................................................. 45 3.18.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 46 3.19 CONPR_R01_STA036_XPT 3185.98 FT MD ........................................................................................................................... 47 3.19.1 Pressure vs. Time Plot ................................................................................................................................................. 47 3.19.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 48 2015-09-20 2 3.20 CONPR_R01_STA037_XPT 3180.93 FT MD ........................................................................................................................... 49 3.20.1 Pressure vs. Time Plot ................................................................................................................................................. 49 3.20.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 50 3.21 CONPR_R01_STA043_XPT 4337.97 FT MD ........................................................................................................................... 51 3.21.1 Pressure vs. Time Plot ................................................................................................................................................. 51 3.21.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 52 3.22 CONPR_R01_STA044_XPT 4250.97 FT MD ........................................................................................................................... 53 3.22.1 Pressure vs. Time Plot ................................................................................................................................................. 53 3.22.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 54 3.23 CONPR_R01_STA045_XPT 4221.96 FT MD ........................................................................................................................... 55 3.23.1 Pressure vs. Time Plot ................................................................................................................................................. 55 3.23.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 56 3.24 CONPR_R01_STA047_XPT 4149.01 FT MD ........................................................................................................................... 57 3.24.1 Pressure vs. Time Plot ................................................................................................................................................. 57 3.24.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 58 3.25 CONPR_R01_STA050_XPT 4131.96 FT MD ........................................................................................................................... 59 3.25.1 Pressure vs. Time Plot ................................................................................................................................................. 59 3.25.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 60 3.26 CONPR_R01_STA051_XPT 4111.96 FT MD ........................................................................................................................... 61 3.26.1 Pressure vs. Time Plot ................................................................................................................................................. 61 3.27 CONPR_R01_STA056_XPT 4046.99 FT MD ........................................................................................................................... 62 3.27.1 Pressure vs. Time Plot ................................................................................................................................................. 62 3.28 CONPR_R01_STA057_XPT 4048 FT MD ................................................................................................................................ 63 3.28.1 Pressure vs. Time Plot ................................................................................................................................................. 63 3.29 CONPR_R01_STA059_XPT 3526.98 FT MD ........................................................................................................................... 64 3.29.1 Pressure vs. Time Plot ................................................................................................................................................. 64 3.29.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 65 3.30 CONPR_R01_STA065_XPT 2846.93 FT MD ........................................................................................................................... 66 3.30.1 Pressure vs. Time Plot ................................................................................................................................................. 66 3.30.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 67 3.31 CONPR_R01_STA071_XPT 2791.45 FT MD ........................................................................................................................... 68 3.31.1 Pressure vs. Time Plot ................................................................................................................................................. 68 3.31.2 FRID, Spherical and Radial Specialized Plots ............................................................................................................... 69 2015-09-20 3 DISCLAIMER ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION FURNISHED WITH THE SERVICES OR OTHERWISE COMMUNICATED BY SCHLUMBERGER TO CUSTOMER AT ANY TIME IN CONNECTION WITH THE SERVICES ARE OPINIONS BASED ON INFERENCES FROM MEASUREMENTS, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS, WHICH INFERENCES, EMPIRICAL RELATIONSHIPS AND/OR ASSUMPTIONS ARE NOT INFALLIBLE, AND WITH RESPECT TO WHICH PROFESSIONALS IN THE INDUSTRY MAY DIFFER. ACCORDINGLY, SCHLUMBERGER CANNOT AND DOES NOT WARRANT THE ACCURACY, CORRECTNESS OR COMPLETENESS OF ANY SUCH INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES OR RECOMMENDATION. CUSTOMER ACKNOWLEDGES THAT IT IS ACCEPTING THE SERVICES "AS IS", THAT SCHLUMBERGER MAKES NO REPRESENTATION OR WARRANTY, EXPRESS OR IMPLIED, OF ANY KIND OR DESCRIPTION IN RESPECT THERETO. SPECIFICALLY, CUSTOMER ACKNOWLEDGES THAT SCHLUMBERGER DOES NOT WARRANT THAT ANY INTERPRETATION, RESEARCH, ANALYSIS, DATA, RESULTS, ESTIMATES, OR RECOMMENDATION IS FIT FOR A PARTICULAR PURPOSE, INCLUDING BUT NOT LIMITED TO COMPLIANCE WITH ANY GOVERNMENT REQUEST OR REGULATORY REQUIREMENT. CUSTOMER FURTHER ACKNOWLEDGES THAT SUCH SERVICES ARE DELIVERED WITH THE EXPLICIT UNDERSTANDING AND AGREEMENT THAT ANY ACTION TAKEN BASED ON THE SERVICES RECEIVED SHALL BE AT ITS OWN RISK AND RESPONSIBILITY AND NO CLAIM SHALL BE MADE AGAINST SCHLUMBERGER AS A CONSEQUENCE THEREOF. 2015-09-20 4 1 Well and Job Data 1.1 Well Survey Table Figure 1 Survey Top View Figure 2 Survey Side View -1000 -800 -600 -400 -200 0 200 400 600 800 1000 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 Survey Top View View Azimuth: 90 S <----> N (f t ) W <----> E (ft) 4500 4000 3500 3000 2500 2000 1500 1000 500 0 -2000 -1500 -1000 -500 0 500 1000 1500 2000 Survey Side View View Azimuth: 90 T V D (f t ) ft 2015-09-20 5 Table 1 Survey Table # MD (ft) Incl (deg) Azim (deg) TVD (ft) North (ft) East (ft) Dep.Azim. (deg) Dog Leg Sev. (deg/100ft) 1 18 0 0 18 0 0 0 0 2 18 0 0 18 0 0 0 0 3 105.32 0.17 170.85 105.32 -0.13 0.02 170.85 0.19 4 170.07 0.19 170.85 170.07 -0.33 0.05 170.85 0.03 5 229.6 0.22 121.04 229.6 -0.49 0.17 161.05 0.29 6 292.47 0.31 136.72 292.47 -0.67 0.39 150.06 0.18 7 359.12 1.13 223.99 359.11 -1.28 0.05 177.59 1.74 8 421.42 3.83 234.12 421.35 -2.94 -2.06 215.03 4.37 9 482.88 5.44 233.76 482.61 -5.86 -6.07 226.01 2.62 10 544.77 8.85 234.88 544.01 -10.34 -12.33 230.03 5.51 11 605.75 11.13 235.34 604.06 -16.38 -21.01 232.06 3.74 12 667.69 14.4 236.97 664.46 -23.98 -32.39 233.48 5.31 13 728.27 16.14 236.72 722.9 -32.71 -45.75 234.43 2.87 14 790.92 18.98 235.26 782.62 -43.3 -61.4 234.81 4.59 15 852.59 20.96 234.35 840.58 -55.44 -78.61 234.8 3.25 16 914.79 24.84 233.47 897.87 -69.71 -98.15 234.62 6.26 17 976.72 26.5 233.83 953.69 -85.61 -119.76 234.44 2.69 18 1038.07 28.87 233.91 1008.01 -102.41 -142.78 234.35 3.86 19 1100.26 31.64 232.96 1061.72 -121.08 -167.94 234.21 4.52 20 1160.65 31.68 233.24 1113.13 -140.12 -193.29 234.06 0.25 21 1223.63 31.43 233.48 1166.79 -159.79 -219.73 233.98 0.44 22 1287.09 31.94 233.5 1220.79 -179.62 -246.52 233.92 0.8 23 1349.38 32.83 234.08 1273.4 -199.32 -273.44 233.91 1.51 24 1411.43 32.87 234.59 1325.52 -218.95 -300.79 233.95 0.45 25 1473.12 32.72 234.17 1377.38 -238.41 -327.95 233.98 0.44 26 1534.54 32.35 234.44 1429.16 -257.68 -354.78 234.01 0.65 27 1597.21 31.98 234.92 1482.21 -276.97 -382 234.06 0.72 28 1659.02 31.83 235.09 1534.68 -295.71 -408.76 234.12 0.28 29 1721.75 32.34 233.48 1587.83 -315.16 -435.81 234.13 1.59 30 1783.77 32.4 234.29 1640.22 -334.73 -462.63 234.11 0.71 31 1845.6 32.26 233.62 1692.46 -354.18 -489.37 234.1 0.62 32 1907.69 32.32 233.33 1744.95 -373.93 -516.02 234.07 0.27 33 1969.81 32.69 233.54 1797.34 -393.81 -542.83 234.04 0.62 34 2031.36 32.89 233.72 1849.08 -413.58 -569.67 234.02 0.36 35 2093.38 32.9 233.5 1901.16 -433.56 -596.79 234 0.19 36 2155.23 33.39 233.71 1952.94 -453.63 -624.01 233.98 0.81 37 2216.9 33.59 233.8 2004.38 -473.75 -651.46 233.97 0.33 38 2277.74 32.63 232.39 2055.34 -493.7 -678.03 233.94 2.02 39 2341.24 32.85 232.43 2108.75 -514.65 -705.24 233.88 0.35 40 2402.93 31.63 231.47 2160.93 -534.92 -731.16 233.81 2.14 41 2465.54 31.93 231.3 2214.15 -555.5 -756.93 233.73 0.5 42 2488.57 32.11 231.19 2233.68 -563.15 -766.45 233.69 0.82 43 2577.49 30.17 236.26 2309.79 -590.38 -803.45 233.69 3.67 44 2639.26 28.62 234.34 2363.61 -607.62 -828.38 233.74 2.94 45 2701.14 26.62 236.26 2418.44 -623.97 -851.96 233.78 3.54 46 2762.92 23.86 236.41 2474.31 -638.57 -873.88 233.84 4.47 47 2825.92 22.22 235.91 2532.29 -652.3 -894.36 233.9 2.62 48 2888.05 20.15 235.79 2590.21 -664.9 -912.94 233.93 3.33 49 2950.08 17.82 236.02 2648.87 -676.21 -929.65 233.97 3.76 50 3012.5 15.65 236.63 2708.64 -686.18 -944.6 234 3.49 51 3074.02 12.74 238.49 2768.27 -694.29 -957.32 234.05 4.79 2015-09-20 6 52 3136.83 10.41 237.78 2829.8 -700.94 -968.02 234.09 3.72 53 3196.92 7.86 236.52 2889.13 -706.1 -976.04 234.12 4.26 54 3259.7 4.79 227.71 2951.52 -710.23 -981.57 234.11 5.11 55 3321.32 2.95 250.78 3013 -712.49 -984.97 234.12 3.85 56 3382.65 0.9 285.22 3074.29 -712.88 -986.92 234.16 3.69 57 3444.89 1.07 334.05 3136.52 -712.23 -987.65 234.2 1.33 58 3506.8 1.19 337.02 3198.42 -711.12 -988.15 234.26 0.22 59 3570.08 0.72 216.95 3261.7 -710.83 -988.65 234.28 2.64 60 3631.91 0.69 206.17 3323.52 -711.48 -989.04 234.27 0.22 61 3692.52 0.99 209.85 3384.13 -712.26 -989.47 234.25 0.5 62 3756.42 0.75 204.72 3448.02 -713.12 -989.92 234.23 0.39 63 3818.47 1.01 195.84 3510.06 -714.01 -990.24 234.21 0.47 64 3879.05 0.76 212.04 3570.63 -714.87 -990.59 234.18 0.58 65 3942.64 0.62 211.4 3634.22 -715.52 -991 234.17 0.22 66 4004.57 0.78 192.61 3696.14 -716.21 -991.26 234.15 0.45 67 4065.99 0.72 205.25 3757.56 -716.97 -991.52 234.13 0.29 68 4126.31 0.98 176.67 3817.87 -717.83 -991.65 234.1 0.81 69 4189.32 1 184 3880.87 -718.91 -991.66 234.06 0.2 70 4252.79 0.98 202.73 3944.33 -719.97 -991.91 234.03 0.51 71 4314.35 1.06 177.06 4005.88 -721.02 -992.08 233.99 0.75 72 4376.33 1.07 181.08 4067.85 -722.17 -992.06 233.95 0.12 73 4438.14 1.1 178.24 4129.65 -723.34 -992.05 233.9 0.1 74 4470 1.1 178.24 4161.51 -723.95 -992.04 233.88 0 2015-09-20 7 2 Test Point Table Table 2 Pressure Related Results File No. Test No. Probe MD Probe TVD DD Mobility Mud Pres. Before Mud Pres. After Last BU Pres. Formation Pres. Temp. After Gauge Type Packer/Probe Type Pretest Type ft ft mD/cP psi psi psi psi degF 1 2 3994.02 3685.60 1.18 1751.511 1751.195 1414.279 1414.279 85.27 QCP Standard packer Volumetric Drawdown 2 3 3981.84 3673.42 1745.343 1745.470 803.622 86.16 QCP Standard packer Volumetric Drawdown 3 5 3982.38 3673.95 0.34 1745.287 1745.574 1414.022 1414.022 87.33 QCP Standard packer Volumetric Drawdown 4 7 3740.01 3431.61 7.25 1630.566 1630.624 1335.677 1335.677 87.85 QCP Standard packer Volumetric Drawdown 5 8 3714.96 3406.56 1618.344 1618.505 1618.390 88.29 QCP Standard packer Volumetric Drawdown 6 9 3715.45 3407.05 1618.440 1618.694 1618.516 88.35 QCP Standard packer Volumetric Drawdown 7 11 3706.05 3397.65 0.12 1614.191 1614.167 1327.544 1327.544 88.39 QCP Standard packer Volumetric Drawdown 8 13 3689.99 3381.60 0.42 1606.635 1606.541 1326.276 1326.276 88.27 QCP Standard packer Volumetric Drawdown 9 15 3555.00 3246.62 0.29 1542.584 1542.399 1254.480 1254.480 88.03 QCP Standard packer Volumetric Drawdown 10 16 3531.01 3222.63 1531.084 1531.100 1530.951 87.85 QCP Standard packer Volumetric Drawdown 11 17 3530.48 3222.10 1530.711 1530.885 1530.663 87.75 QCP Standard packer Volumetric Drawdown 12 18 3531.47 3223.09 1531.190 1531.357 1531.204 87.64 QCP Standard packer Volumetric Drawdown 13 19 3521.98 3213.60 1526.766 1526.883 1526.726 87.48 QCP Standard packer Volumetric Drawdown 14 20 3522.98 3214.59 1527.218 1527.337 1527.179 87.35 QCP Standard packer Volumetric Drawdown 15 21 3524.01 3215.63 1527.631 1527.679 87.28 QCP Standard packer Volumetric Drawdown 16 24 3469.97 3161.59 1502.302 1502.241 87.03 QCP Standard packer Volumetric Drawdown 17 26 3470.53 3162.15 0.10 1502.331 1502.493 620.566 620.566 86.90 QCP Standard packer Volumetric Drawdown 18 28 3460.02 3151.65 0.18 1497.423 1497.617 621.221 621.221 86.72 QCP Standard packer Volumetric Drawdown 19 29 3452.01 3143.64 1493.659 1493.935 550.651 86.63 QCP Standard packer Volumetric 2015-09-20 8 File No. Test No. Probe MD Probe TVD DD Mobility Mud Pres. Before Mud Pres. After Last BU Pres. Formation Pres. Temp. After Gauge Type Packer/Probe Type Pretest Type Drawdown 20 31 3454.00 3145.63 0.08 1494.576 1494.740 620.925 620.925 86.57 QCP Standard packer Volumetric Drawdown 21 33 3448.01 3139.64 1.09 1491.689 1491.940 621.216 621.216 86.50 QCP Standard packer Volumetric Drawdown 22 35 3379.94 3071.58 0.12 1459.788 1459.664 1186.678 1186.678 86.22 QCP Standard packer Volumetric Drawdown 23 37 3365.99 3057.64 1.64 1453.100 1453.081 1180.780 1180.780 85.89 QCP Standard packer Volumetric Drawdown 24 39 3356.98 3048.63 0.86 1448.819 1448.817 1179.724 1179.724 85.65 QCP Standard packer Volumetric Drawdown 25 40 3284.98 2976.72 1415.420 1415.258 1415.289 85.34 QCP Standard packer Volumetric Drawdown 26 42 3284.49 2976.24 1415.062 1415.118 1414.964 85.05 QCP Standard packer Volumetric Drawdown 27 43 3286.52 2978.26 1415.980 1416.116 1415.964 84.89 QCP Standard packer Volumetric Drawdown 28 45 3265.00 2956.80 0.36 1405.933 1405.855 1145.068 1145.068 84.64 QCP Standard packer Volumetric Drawdown 29 47 3246.98 2938.84 5.81 1397.376 1397.374 1139.714 1139.714 84.54 QCP Standard packer Volumetric Drawdown 30 49 3234.97 2926.89 0.11 1391.608 1391.500 1134.379 1134.379 84.31 QCP Standard packer Volumetric Drawdown 31 51 3228.01 2919.98 1388.263 1388.527 1388.304 83.95 QCP Standard packer Volumetric Drawdown 32 53 3225.96 2917.94 0.54 1387.438 1387.515 1130.576 1130.576 83.85 QCP Standard packer Volumetric Drawdown 33 54 3219.95 2911.97 1384.647 1384.790 1384.652 83.76 QCP Standard packer Volumetric Drawdown 34 55 3220.48 2912.50 1384.883 1384.847 1384.873 83.74 QCP Standard packer Volumetric Drawdown 35 56 3221.01 2913.02 1385.125 1385.290 1385.150 83.72 QCP Standard packer Volumetric Drawdown 36 58 3185.98 2878.29 2.86 1368.181 1368.084 1121.076 1121.076 83.62 QCP Standard packer Volumetric Drawdown 37 60 3180.93 2873.30 0.34 1365.609 1365.928 1118.418 1118.418 83.46 QCP Standard packer Volumetric Drawdown 38 61 3148.98 2841.76 1350.894 1350.800 1350.826 83.33 QCP Standard packer Volumetric Drawdown 39 62 3147.99 2840.79 1350.281 1350.621 1350.340 83.19 QCP Standard packer Volumetric 2015-09-20 9 File No. Test No. Probe MD Probe TVD DD Mobility Mud Pres. Before Mud Pres. After Last BU Pres. Formation Pres. Temp. After Gauge Type Packer/Probe Type Pretest Type Drawdown 40 63 3147.01 2839.82 1349.930 1349.885 1349.892 83.06 QCP Standard packer Volumetric Drawdown 41 64 4341.94 4033.47 1917.331 1916.768 1916.752 86.93 QCP Standard packer Volumetric Drawdown 42 66 4340.97 4032.50 1916.323 1916.432 87.90 QCP Standard packer Volumetric Drawdown 43 68 4337.97 4029.50 0.01 1914.687 1914.760 1634.283 1634.283 89.38 QCP Standard packer Volumetric Drawdown 44 70 4250.97 3942.51 0.11 1873.717 1873.731 1553.810 1553.810 89.89 QCP Standard packer Volumetric Drawdown 45 72 4221.96 3913.51 0.30 1859.965 1859.968 1441.038 1441.038 90.17 QCP Standard packer Volumetric Drawdown 46 73 4149.98 3841.54 1826.124 1826.088 1825.808 90.19 QCP Standard packer Volumetric Drawdown 47 76 4149.01 3840.57 0.44 1825.249 1825.376 1342.029 1342.029 90.26 QCP Standard packer Volumetric Drawdown 48 77 4129.98 3821.54 1816.202 1816.581 1816.440 90.18 QCP Standard packer Volumetric Drawdown 49 78 4130.99 3822.55 1816.647 1816.997 1816.907 90.16 QCP Standard packer Volumetric Drawdown 50 80 4131.96 3823.52 0.13 1817.308 1817.472 1354.841 1354.841 90.20 QCP Standard packer Volumetric Drawdown 51 83 4111.96 3803.52 1807.849 1808.043 90.29 QCP Standard packer Volumetric Drawdown 52 84 4113.00 3804.56 1808.268 1808.538 1807.996 90.12 QCP Standard packer Volumetric Drawdown 53 85 4113.97 3805.53 1808.840 1808.908 1808.739 90.07 QCP Standard packer Volumetric Drawdown 54 86 4111.00 3802.56 1807.312 1807.675 1807.544 90.04 QCP Standard packer Volumetric Drawdown 55 87 4045.96 3737.53 1776.867 1776.874 1776.886 90.02 QCP Standard packer Volumetric Drawdown 56 89 4046.99 3738.56 1777.241 1777.291 90.12 QCP Standard packer Volumetric Drawdown 57 90 4048.00 3739.57 1777.428 1777.831 393.688 90.04 QCP Standard packer Volumetric Drawdown 58 91 3525.01 3216.63 1529.099 1529.198 1528.715 88.39 QCP Standard packer Volumetric Drawdown 59 93 3526.98 3218.60 6.27 1529.751 1529.969 1247.625 1247.625 87.63 QCP Standard packer Volumetric 2015-09-20 10 File No. Test No. Probe MD Probe TVD DD Mobility Mud Pres. Before Mud Pres. After Last BU Pres. Formation Pres. Temp. After Gauge Type Packer/Probe Type Pretest Type Drawdown 60 94 2961.02 2659.29 1264.825 1264.810 84.95 QCP Standard packer Volumetric Drawdown 61 95 2960.00 2658.32 1264.328 1264.303 1264.308 83.97 QCP Standard packer Volumetric Drawdown 62 96 2963.00 2661.18 1265.503 1265.688 1265.624 83.28 QCP Standard packer Volumetric Drawdown 63 97 2851.00 2555.57 1215.810 1215.891 1215.702 82.31 QCP Standard packer Volumetric Drawdown 64 98 2848.96 2553.67 1214.775 1214.922 1214.760 81.77 QCP Standard packer Volumetric Drawdown 65 101 2846.93 2551.79 14.76 1213.911 1214.256 1014.794 1014.794 80.68 QCP Standard packer Volumetric Drawdown 66 102 2842.93 2548.07 1212.431 1212.220 80.30 QCP Standard packer Volumetric Drawdown 67 103 2841.96 2547.16 1211.696 1211.967 1211.444 80.06 QCP Standard packer Volumetric Drawdown 68 104 2789.89 2499.05 1189.171 1189.012 1188.811 79.75 QCP Standard packer Volumetric Drawdown 70 105 2790.45 2499.56 1189.122 1189.725 1189.162 79.53 QCP Standard packer Volumetric Drawdown 71 108 2791.45 2500.48 0.24 1189.613 1191.360 1005.247 1005.247 78.71 QCP Standard packer Volumetric Drawdown 2015-09-20 11 3 Stations 3.1 ConPr_R01_Sta001_XPT 3994.02 ft MD 3.1.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1414.279 (psi) Last Read Buildup Pressure : 1414.279 (psi) Drawdown Mobility: 1.18 (mD/cP) Mud Pressure Before: 1751.511 (psi) Mud Pressure After: 1751.195 (psi) Temperature Before: 83.04 (degF) Temperature After: 85.27 (degF) Pretest Rate: 0.46 (cm3/s) Pretest Volume: 4.87 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:2 Probe MD:3994.02ft Probe TVD:3685.6ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta001_XPT Swanson River Unit 213-15 Mud Before(1751.511psi)Start Drawdown(1414.298psi)Start Buildup(1401.62psi)Last Buildup(1414.279psi)Mud After(1751.195psi) p s i c m 3 d e g F ETIM_XPT (s) 0 50 100 150 200 250 300 350 400 1400 1450 1500 1550 1600 1650 1700 1750 1800 -10 0 10 83.0 83.5 84.0 84.5 85.0 85.5 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 12 3.1.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1414.279 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1414.279 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:2 Probe MD:3994.02ft Probe TVD:3685.6ft Delta Time 10 0 10 1 10 2 -210 -110 010 110 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1408.5 1409.0 1409.5 1410.0 1410.5 1411.0 1411.5 1412.0 1412.5 1413.0 1413.5 1414.0 1414.5 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1408.5 1409.0 1409.5 1410.0 1410.5 1411.0 1411.5 1412.0 1412.5 1413.0 1413.5 1414.0 1414.5 Radial Pressure(psi) 2015-09-20 13 3.2 ConPr_R01_Sta003_XPT 3982.38 ft MD 3.2.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1414.022 (psi) Last Read Buildup Pressure : 1414.022 (psi) Drawdown Mobility: 0.34 (mD/cP) Mud Pressure Before: 1745.287 (psi) Mud Pressure After: 1745.574 (psi) Temperature Before: 86.41 (degF) Temperature After: 87.33 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 5 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:5 Probe MD:3982.38ft Probe TVD:3673.95ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta003_XPT Swanson River Unit 213-15 Mud Before(1745.287psi)Start Drawdown(1413.701psi)Start Buildup(1342.268psi)Last Buildup(1414.022psi)Mud After(1745.574psi) p s i c m 3 d e g F ETIM_XPT (s) 0 50 100 150 200 250 300 350 1350 1400 1450 1500 1550 1600 1650 1700 1750 -10 0 10 86.4 86.6 86.8 87.0 87.2 87.4 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 14 3.2.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1414.022 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1414.022 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:5 Probe MD:3982.38ft Probe TVD:3673.95ft Delta Time 10 0 10 1 10 2 010 02*10 04*10 06*10 08*10 110 12*10 14*10 16*10 18*10 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1350 1355 1360 1365 1370 1375 1380 1385 1390 1395 1400 1405 1410 1415 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1350 1355 1360 1365 1370 1375 1380 1385 1390 1395 1400 1405 1410 1415 Radial Pressure(psi) 2015-09-20 15 3.3 ConPr_R01_Sta004_XPT 3740.01 ft MD 3.3.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1335.677 (psi) Last Read Buildup Pressure : 1335.677 (psi) Drawdown Mobility: 7.25 (mD/cP) Mud Pressure Before: 1630.566 (psi) Mud Pressure After: 1630.624 (psi) Temperature Before: 87.84 (degF) Temperature After: 87.85 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.91 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:7 Probe MD:3740.01ft Probe TVD:3431.61ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta004_XPT Swanson River Unit 213-15 Mud Before(1630.566psi)Mud After(1630.624psi)Start Drawdown(1335.681psi)Start Buildup(1331.914psi)Last Buildup(1335.677psi) p s i c m 3 d e g F ETIM_XPT (s) 0 50 100 150 200 250 300 1350 1400 1450 1500 1550 1600 1650 0 10 20 87.8 87.9 88.0 88.1 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 16 3.3.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1335.677 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1335.677 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:7 Probe MD:3740.01ft Probe TVD:3431.61ft Delta Time 10 0 10 1 10 2 -310 -210 -110 010 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1332.5 1333.0 1333.5 1334.0 1334.5 1335.0 1335.5 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1332.5 1333.0 1333.5 1334.0 1334.5 1335.0 1335.5 Radial Pressure(psi) 2015-09-20 17 3.4 ConPr_R01_Sta007_XPT 3706.05 ft MD 3.4.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1327.544 (psi) Last Read Buildup Pressure : 1327.544 (psi) Drawdown Mobility: 0.12 (mD/cP) Mud Pressure Before: 1614.191 (psi) Mud Pressure After: 1614.167 (psi) Temperature Before: 88.35 (degF) Temperature After: 88.39 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.85 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:11 Probe MD:3706.05ft Probe TVD:3397.65ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta007_XPT Swanson River Unit 213-15 Mud Before(1614.191psi)Start Drawdown(1326.526psi)Start Buildup(1115.039psi)Last Buildup(1327.544psi)Mud After(1614.167psi) p s i c m 3 d e g F ETIM_XPT (s) 0 50 100 150 200 250 300 350 400 450 500 550 600 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 1600 1650 0 10 20 88.26 88.28 88.30 88.32 88.34 88.36 88.38 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 18 3.4.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1327.544 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1327.544 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:11 Probe MD:3706.05ft Probe TVD:3397.65ft Delta Time 10 0 10 1 10 2 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1120 1140 1160 1180 1200 1220 1240 1260 1280 1300 1320 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1120 1140 1160 1180 1200 1220 1240 1260 1280 1300 1320 Radial Pressure(psi) 2015-09-20 19 3.5 ConPr_R01_Sta008_XPT 3689.99 ft MD 3.5.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1326.276 (psi) Last Read Buildup Pressure : 1326.276 (psi) Drawdown Mobility: 0.42 (mD/cP) Mud Pressure Before: 1606.635 (psi) Mud Pressure After: 1606.541 (psi) Temperature Before: 88.32 (degF) Temperature After: 88.27 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.93 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:13 Probe MD:3689.99ft Probe TVD:3381.6ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta008_XPT Swanson River Unit 213-15 Mud Before(1606.635psi)Start Drawdown(1326.15psi)Start Buildup(1264.188psi)Last Buildup(1326.276psi)Mud After(1606.541psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 1250 1300 1350 1400 1450 1500 1550 1600 -10 0 10 20 88.22 88.24 88.26 88.28 88.30 88.32 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 20 3.5.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1326.276 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1326.276 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:13 Probe MD:3689.99ft Probe TVD:3381.6ft Delta Time 10 0 10 1 10 2 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1265 1270 1275 1280 1285 1290 1295 1300 1305 1310 1315 1320 1325 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1265 1270 1275 1280 1285 1290 1295 1300 1305 1310 1315 1320 1325 Radial Pressure(psi) 2015-09-20 21 3.6 ConPr_R01_Sta009_XPT 3555 ft MD 3.6.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1254.48 (psi) Last Read Buildup Pressure : 1254.48 (psi) Drawdown Mobility: 0.29 (mD/cP) Mud Pressure Before: 1542.584 (psi) Mud Pressure After: 1542.399 (psi) Temperature Before: 88.17 (degF) Temperature After: 88.03 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.93 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:15 Probe MD:3555ft Probe TVD:3246.62ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta009_XPT Swanson River Unit 213-15 Mud Before(1542.584psi)Start Drawdown(1253.468psi)Start Buildup(1163.974psi)Last Buildup(1254.48psi)Mud After(1542.399psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 1150 1200 1250 1300 1350 1400 1450 1500 1550 -20 -10 0 10 20 88.00 88.05 88.10 88.15 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 22 3.6.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1254.48 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1254.48 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:15 Probe MD:3555ft Probe TVD:3246.62ft Delta Time 10 0 10 1 10 2 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1170 1180 1190 1200 1210 1220 1230 1240 1250 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1170 1180 1190 1200 1210 1220 1230 1240 1250 Radial Pressure(psi) 2015-09-20 23 3.7 ConPr_R01_Sta017_XPT 3470.52 ft MD 3.7.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 620.566 (psi) Last Read Buildup Pressure : 620.566 (psi) Drawdown Mobility: 0.1 (mD/cP) Mud Pressure Before: 1502.331 (psi) Mud Pressure After: 1502.493 (psi) Temperature Before: 87 (degF) Temperature After: 86.9 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 4.97 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:26 Probe MD:3470.53ft Probe TVD:3162.15ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta017_XPT Swanson River Unit 213-15 Mud Before(1502.331psi)Start Drawdown(619.984psi)Start Buildup(510.774psi)Last Buildup(620.566psi)Mud After(1502.493psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 9 10 500 600 700 800 900 1000 1100 1200 1300 1400 1500 0 5 10 15 86.75 86.80 86.85 86.90 86.95 87.00 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 24 3.7.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 620.566 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 620.566 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:26 Probe MD:3470.53ft Probe TVD:3162.15ft Delta Time 10 0 10 1 10 2 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 510 520 530 540 550 560 570 580 590 600 610 620 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 510 520 530 540 550 560 570 580 590 600 610 620 Radial Pressure(psi) 2015-09-20 25 3.8 ConPr_R01_Sta018_XPT 3460.02 ft MD 3.8.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 621.221 (psi) Last Read Buildup Pressure : 621.221 (psi) Drawdown Mobility: 0.18 (mD/cP) Mud Pressure Before: 1497.423 (psi) Mud Pressure After: 1497.617 (psi) Temperature Before: 86.79 (degF) Temperature After: 86.72 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 4.88 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:28 Probe MD:3460.02ft Probe TVD:3151.65ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta018_XPT Swanson River Unit 213-15 Mud Before(1497.423psi)Start Drawdown(619.696psi)Start Buildup(515.344psi)Last Buildup(621.221psi)Mud After(1497.617psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 500 600 700 800 900 1000 1100 1200 1300 1400 1500 0 10 86.55 86.60 86.65 86.70 86.75 86.80 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 26 3.8.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 621.221 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 621.221 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:28 Probe MD:3460.02ft Probe TVD:3151.65ft Delta Time 10 0 10 1 10 2 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 520 530 540 550 560 570 580 590 600 610 620 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 520 530 540 550 560 570 580 590 600 610 620 Radial Pressure(psi) 2015-09-20 27 3.9 ConPr_R01_Sta019_XPT 3452.01 ft MD 3.9.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 550.651 (psi) Drawdown Mobility: Mud Pressure Before: 1493.659 (psi) Mud Pressure After: 1493.935 (psi) Temperature Before: 86.62 (degF) Temperature After: 86.63 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.88 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:29 Probe MD:3452.01ft Probe TVD:3143.64ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta019_XPT Swanson River Unit 213-15 Mud Before(1493.659psi)Start Drawdown(1445.636psi)Start Buildup(497.8psi)Last Buildup(550.651psi)Mud After(1493.935psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 500 600 700 800 900 1000 1100 1200 1300 1400 1500 0 5 10 86.40 86.45 86.50 86.55 86.60 86.65 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 28 3.10 ConPr_R01_Sta020_XPT 3454 ft MD 3.10.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 620.925 (psi) Last Read Buildup Pressure : 620.925 (psi) Drawdown Mobility: 0.08 (mD/cP) Mud Pressure Before: 1494.576 (psi) Mud Pressure After: 1494.74 (psi) Temperature Before: 86.54 (degF) Temperature After: 86.57 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 4.89 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:31 Probe MD:3454ft Probe TVD:3145.63ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta020_XPT Swanson River Unit 213-15 Mud Before(1494.576psi)Start Drawdown(620.316psi)Start Buildup(476.626psi)Last Buildup(620.925psi)Mud After(1494.74psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 500 600 700 800 900 1000 1100 1200 1300 1400 1500 -10 0 10 86.35 86.40 86.45 86.50 86.55 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 29 3.10.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 620.925 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 620.925 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:31 Probe MD:3454ft Probe TVD:3145.63ft Delta Time 10 0 10 1 10 2 010 110 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 480 500 520 540 560 580 600 620 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 480 500 520 540 560 580 600 620 Radial Pressure(psi) 2015-09-20 30 3.11 ConPr_R01_Sta021_XPT 3448.01 ft MD 3.11.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 621.216 (psi) Last Read Buildup Pressure : 621.216 (psi) Drawdown Mobility: 1.09 (mD/cP) Mud Pressure Before: 1491.689 (psi) Mud Pressure After: 1491.94 (psi) Temperature Before: 86.49 (degF) Temperature After: 86.5 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 4.95 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:33 Probe MD:3448.01ft Probe TVD:3139.64ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta021_XPT Swanson River Unit 213-15 Mud Before(1491.689psi)Start Drawdown(621.353psi)Start Buildup(598.325psi)Last Buildup(621.216psi)Mud After(1491.94psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 600 700 800 900 1000 1100 1200 1300 1400 1500 0 10 86.30 86.35 86.40 86.45 86.50 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 31 3.11.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 621.216 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 621.216 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:33 Probe MD:3448.01ft Probe TVD:3139.64ft Delta Time 10 0 10 1 10 2 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 600 602 604 606 608 610 612 614 616 618 620 622 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 600 602 604 606 608 610 612 614 616 618 620 622 Radial Pressure(psi) 2015-09-20 32 3.12 ConPr_R01_Sta022_XPT 3379.94 ft MD 3.12.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1186.678 (psi) Last Read Buildup Pressure : 1186.678 (psi) Drawdown Mobility: 0.12 (mD/cP) Mud Pressure Before: 1459.788 (psi) Mud Pressure After: 1459.664 (psi) Temperature Before: 86.35 (degF) Temperature After: 86.22 (degF) Pretest Rate: 0.47 (cm3/s) Pretest Volume: 4.89 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:35 Probe MD:3379.94ft Probe TVD:3071.58ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta022_XPT Swanson River Unit 213-15 Mud Before(1459.788psi)Start Drawdown(1186.226psi)Start Buildup(967.886psi)Last Buildup(1186.678psi)Mud After(1459.664psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 0 10 86.20 86.25 86.30 86.35 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 33 3.12.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1186.678 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1186.678 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:35 Probe MD:3379.94ft Probe TVD:3071.58ft Delta Time 10 0 10 1 10 2 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 980 1000 1020 1040 1060 1080 1100 1120 1140 1160 1180 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 980 1000 1020 1040 1060 1080 1100 1120 1140 1160 1180 Radial Pressure(psi) 2015-09-20 34 3.13 ConPr_R01_Sta023_XPT 3365.99 ft MD 3.13.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1180.78 (psi) Last Read Buildup Pressure : 1180.78 (psi) Drawdown Mobility: 1.64 (mD/cP) Mud Pressure Before: 1453.1 (psi) Mud Pressure After: 1453.081 (psi) Temperature Before: 86.11 (degF) Temperature After: 85.89 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.79 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:37 Probe MD:3365.99ft Probe TVD:3057.64ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta023_XPT Swanson River Unit 213-15 Mud Before(1453.1psi)Start Drawdown(1180.741psi)Start Buildup(1164.592psi)Last Buildup(1180.78psi)Mud After(1453.081psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 1150 1200 1250 1300 1350 1400 1450 -10 0 10 20 85.85 85.90 85.95 86.00 86.05 86.10 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 35 3.13.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1180.78 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1180.78 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:37 Probe MD:3365.99ft Probe TVD:3057.64ft Delta Time 10 0 10 1 10 2 -210 -110 010 110 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1166 1168 1170 1172 1174 1176 1178 1180 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1166 1168 1170 1172 1174 1176 1178 1180 Radial Pressure(psi) 2015-09-20 36 3.14 ConPr_R01_Sta024_XPT 3356.98 ft MD 3.14.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1179.724 (psi) Last Read Buildup Pressure : 1179.724 (psi) Drawdown Mobility: 0.86 (mD/cP) Mud Pressure Before: 1448.819 (psi) Mud Pressure After: 1448.817 (psi) Temperature Before: 85.8 (degF) Temperature After: 85.65 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.82 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:39 Probe MD:3356.98ft Probe TVD:3048.63ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta024_XPT Swanson River Unit 213-15 Mud Before(1448.819psi)Start Drawdown(1179.637psi)Start Buildup(1153.73psi)Last Buildup(1179.724psi)Mud After(1448.817psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 1150 1200 1250 1300 1350 1400 1450 0 10 20 85.65 85.70 85.75 85.80 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 37 3.14.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1179.724 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1179.724 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:39 Probe MD:3356.98ft Probe TVD:3048.63ft Delta Time 10 0 10 1 10 2 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1155 1160 1165 1170 1175 1180 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1155 1160 1165 1170 1175 1180 Radial Pressure(psi) 2015-09-20 38 3.15 ConPr_R01_Sta028_XPT 3265 ft MD 3.15.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1145.068 (psi) Last Read Buildup Pressure : 1145.068 (psi) Drawdown Mobility: 0.36 (mD/cP) Mud Pressure Before: 1405.933 (psi) Mud Pressure After: 1405.855 (psi) Temperature Before: 84.8 (degF) Temperature After: 84.64 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.96 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:45 Probe MD:3265ft Probe TVD:2956.8ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta028_XPT Swanson River Unit 213-15 Mud Before(1405.933psi)Start Drawdown(1144.919psi)Start Buildup(1070.675psi)Last Buildup(1145.068psi)Mud After(1405.855psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 1100 1150 1200 1250 1300 1350 1400 -10 0 10 20 84.60 84.65 84.70 84.75 84.80 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 39 3.15.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1145.068 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1145.068 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:45 Probe MD:3265ft Probe TVD:2956.8ft Delta Time 10 0 10 1 10 2 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1090 1095 1100 1105 1110 1115 1120 1125 1130 1135 1140 1145 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1090 1095 1100 1105 1110 1115 1120 1125 1130 1135 1140 1145 Radial Pressure(psi) 2015-09-20 40 3.16 ConPr_R01_Sta029_XPT 3246.98 ft MD 3.16.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1139.714 (psi) Last Read Buildup Pressure : 1139.714 (psi) Drawdown Mobility: 5.81 (mD/cP) Mud Pressure Before: 1397.376 (psi) Mud Pressure After: 1397.374 (psi) Temperature Before: 84.55 (degF) Temperature After: 84.54 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.93 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:47 Probe MD:3246.98ft Probe TVD:2938.84ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta029_XPT Swanson River Unit 213-15 Mud Before(1397.376psi)Mud After(1397.374psi)Start Drawdown(1139.711psi)Start Buildup(1135.546psi)Last Buildup(1139.714psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 1150 1200 1250 1300 1350 1400 0 10 20 84.40 84.45 84.50 84.55 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 41 3.16.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1139.714 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1139.714 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:47 Probe MD:3246.98ft Probe TVD:2938.84ft Delta Time 10 0 10 1 10 2 -210 -110 010 110 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1136.5 1137.0 1137.5 1138.0 1138.5 1139.0 1139.5 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1136.5 1137.0 1137.5 1138.0 1138.5 1139.0 1139.5 Radial Pressure(psi) 2015-09-20 42 3.17 ConPr_R01_Sta030_XPT 3234.97 ft MD 3.17.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1134.379 (psi) Last Read Buildup Pressure : 1134.379 (psi) Drawdown Mobility: 0.11 (mD/cP) Mud Pressure Before: 1391.608 (psi) Mud Pressure After: 1391.5 (psi) Temperature Before: 84.32 (degF) Temperature After: 84.31 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.8 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:49 Probe MD:3234.97ft Probe TVD:2926.89ft 17-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta030_XPT Swanson River Unit 213-15 Mud Before(1391.608psi)Mud After(1391.5psi)Start Drawdown(1133.962psi)Start Buildup(912.843psi)Last Buildup(1134.379psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 0 10 20 84.15 84.20 84.25 84.30 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 43 3.17.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1134.379 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1134.379 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:49 Probe MD:3234.97ft Probe TVD:2926.89ft Delta Time 10 0 10 1 10 2 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 920 940 960 980 1000 1020 1040 1060 1080 1100 1120 1140 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 920 940 960 980 1000 1020 1040 1060 1080 1100 1120 1140 Radial Pressure(psi) 2015-09-20 44 3.18 ConPr_R01_Sta032_XPT 3225.96 ft MD 3.18.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1130.576 (psi) Last Read Buildup Pressure : 1130.576 (psi) Drawdown Mobility: 0.54 (mD/cP) Mud Pressure Before: 1387.438 (psi) Mud Pressure After: 1387.515 (psi) Temperature Before: 83.91 (degF) Temperature After: 83.85 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 10.02 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:53 Probe MD:3225.96ft Probe TVD:2917.94ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta032_XPT Swanson River Unit 213-15 Mud Before(1387.438psi)Start Drawdown(1130.799psi)Start Buildup(1094.439psi)Last Buildup(1130.576psi)Mud After(1387.515psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 -10 0 10 20 83.82 83.84 83.86 83.88 83.90 83.92 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 45 3.18.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1130.576 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1130.576 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:53 Probe MD:3225.96ft Probe TVD:2917.94ft Delta Time 10 0 10 1 10 2 -210 -110 010 110 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1105 1110 1115 1120 1125 1130 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1105 1110 1115 1120 1125 1130 Radial Pressure(psi) 2015-09-20 46 3.19 ConPr_R01_Sta036_XPT 3185.98 ft MD 3.19.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1121.076 (psi) Last Read Buildup Pressure : 1121.076 (psi) Drawdown Mobility: 2.86 (mD/cP) Mud Pressure Before: 1368.181 (psi) Mud Pressure After: 1368.084 (psi) Temperature Before: 83.68 (degF) Temperature After: 83.62 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.82 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:58 Probe MD:3185.98ft Probe TVD:2878.29ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta036_XPT Swanson River Unit 213-15 Mud Before(1368.181psi)Start Drawdown(1121.046psi)Start Buildup(1113.641psi)Last Buildup(1121.076psi)Mud After(1368.084psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 1100 1150 1200 1250 1300 1350 0 10 20 83.58 83.60 83.62 83.64 83.66 83.68 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 47 3.19.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1121.076 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1121.076 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:58 Probe MD:3185.98ft Probe TVD:2878.29ft Delta Time 10 0 10 1 10 2 -310 -210 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1114.5 1115.0 1115.5 1116.0 1116.5 1117.0 1117.5 1118.0 1118.5 1119.0 1119.5 1120.0 1120.5 1121.0 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1114.5 1115.0 1115.5 1116.0 1116.5 1117.0 1117.5 1118.0 1118.5 1119.0 1119.5 1120.0 1120.5 1121.0 Radial Pressure(psi) 2015-09-20 48 3.20 ConPr_R01_Sta037_XPT 3180.93 ft MD 3.20.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1118.418 (psi) Last Read Buildup Pressure : 1118.418 (psi) Drawdown Mobility: 0.34 (mD/cP) Mud Pressure Before: 1365.609 (psi) Mud Pressure After: 1365.928 (psi) Temperature Before: 83.55 (degF) Temperature After: 83.46 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.91 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:60 Probe MD:3180.93ft Probe TVD:2873.3ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta037_XPT Swanson River Unit 213-15 Mud Before(1365.609psi)Start Drawdown(1118.442psi)Start Buildup(1050.133psi)Last Buildup(1118.418psi)Mud After(1365.928psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 0 10 20 83.45 83.50 83.55 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 49 3.20.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1118.418 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1118.418 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:60 Probe MD:3180.93ft Probe TVD:2873.3ft Delta Time 10 0 10 1 10 2 -110 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1055 1060 1065 1070 1075 1080 1085 1090 1095 1100 1105 1110 1115 1120 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1055 1060 1065 1070 1075 1080 1085 1090 1095 1100 1105 1110 1115 1120 Radial Pressure(psi) 2015-09-20 50 3.21 ConPr_R01_Sta043_XPT 4337.97 ft MD 3.21.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1634.283 (psi) Last Read Buildup Pressure : 1634.283 (psi) Drawdown Mobility: 0.01 (mD/cP) Mud Pressure Before: 1914.687 (psi) Mud Pressure After: 1914.76 (psi) Temperature Before: 88.13 (degF) Temperature After: 89.38 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 5 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:68 Probe MD:4337.97ft Probe TVD:4029.5ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta043_XPT Swanson River Unit 213-15 Mud Before(1914.687psi)Start Drawdown(1616.362psi)Start Buildup(958.398psi)Last Buildup(1634.283psi)Mud After(1914.76psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 9 10 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 0 5 10 15 88.2 88.4 88.6 88.8 89.0 89.2 89.4 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 51 3.21.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1634.283 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1634.283 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:68 Probe MD:4337.97ft Probe TVD:4029.5ft Delta Time 10 0 10 1 10 2 110 210 310 410 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1000 1100 1200 1300 1400 1500 1600 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1000 1100 1200 1300 1400 1500 1600 Radial Pressure(psi) 2015-09-20 52 3.22 ConPr_R01_Sta044_XPT 4250.97 ft MD 3.22.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1553.81 (psi) Last Read Buildup Pressure : 1553.81 (psi) Drawdown Mobility: 0.11 (mD/cP) Mud Pressure Before: 1873.717 (psi) Mud Pressure After: 1873.731 (psi) Temperature Before: 89.53 (degF) Temperature After: 89.89 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 10.01 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:70 Probe MD:4250.97ft Probe TVD:3942.51ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta044_XPT Swanson River Unit 213-15 Mud Before(1873.717psi)Start Drawdown(1553.237psi)Start Buildup(1338.056psi)Last Buildup(1553.81psi)Mud After(1873.731psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 1200 1300 1400 1500 1600 1700 1800 1900 -10 0 10 20 89.5 89.6 89.7 89.8 89.9 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 53 3.22.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1553.81 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1553.81 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:70 Probe MD:4250.97ft Probe TVD:3942.51ft Delta Time 10 0 10 1 10 2 010 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1360 1380 1400 1420 1440 1460 1480 1500 1520 1540 1560 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1360 1380 1400 1420 1440 1460 1480 1500 1520 1540 1560 Radial Pressure(psi) 2015-09-20 54 3.23 ConPr_R01_Sta045_XPT 4221.96 ft MD 3.23.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1441.038 (psi) Last Read Buildup Pressure : 1441.038 (psi) Drawdown Mobility: 0.3 (mD/cP) Mud Pressure Before: 1859.965 (psi) Mud Pressure After: 1859.968 (psi) Temperature Before: 89.92 (degF) Temperature After: 90.17 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.96 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:72 Probe MD:4221.96ft Probe TVD:3913.51ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta045_XPT Swanson River Unit 213-15 Mud Before(1859.965psi)Start Drawdown(1441.568psi)Start Buildup(1367.957psi)Last Buildup(1441.038psi)Mud After(1859.968psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 0 10 20 89.85 89.90 89.95 90.00 90.05 90.10 90.15 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 55 3.23.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1441.038 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1441.038 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:72 Probe MD:4221.96ft Probe TVD:3913.51ft Delta Time 10 0 10 1 10 2 010 02*10 04*10 06*10 08*10 110 12*10 14*10 16*10 18*10 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1385 1390 1395 1400 1405 1410 1415 1420 1425 1430 1435 1440 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1385 1390 1395 1400 1405 1410 1415 1420 1425 1430 1435 1440 Radial Pressure(psi) 2015-09-20 56 3.24 ConPr_R01_Sta047_XPT 4149.01 ft MD 3.24.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1342.029 (psi) Last Read Buildup Pressure : 1342.029 (psi) Drawdown Mobility: 0.44 (mD/cP) Mud Pressure Before: 1825.249 (psi) Mud Pressure After: 1825.376 (psi) Temperature Before: 90.2 (degF) Temperature After: 90.26 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 4.89 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:76 Probe MD:4149.01ft Probe TVD:3840.57ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta047_XPT Swanson River Unit 213-15 Mud Before(1825.249psi)Start Drawdown(1342.044psi)Start Buildup(1291.538psi)Last Buildup(1342.029psi)Mud After(1825.376psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 1250 1300 1350 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 0 10 20 90.10 90.15 90.20 90.25 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 57 3.24.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1342.029 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1342.029 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:76 Probe MD:4149.01ft Probe TVD:3840.57ft Delta Time 10 0 10 1 10 2 -110 010 110 210 310 Spherical Derivative(psi√s)Radial Derivative(psi) Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1300 1305 1310 1315 1320 1325 1330 1335 1340 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1300 1305 1310 1315 1320 1325 1330 1335 1340 Radial Pressure(psi) 2015-09-20 58 3.25 ConPr_R01_Sta050_XPT 4131.96 ft MD 3.25.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1354.841 (psi) Last Read Buildup Pressure : 1354.841 (psi) Drawdown Mobility: 0.13 (mD/cP) Mud Pressure Before: 1817.308 (psi) Mud Pressure After: 1817.472 (psi) Temperature Before: 90.15 (degF) Temperature After: 90.2 (degF) Pretest Rate: 0.48 (cm3/s) Pretest Volume: 9.77 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:80 Probe MD:4131.96ft Probe TVD:3823.52ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta050_XPT Swanson River Unit 213-15 Mud Before(1817.308psi)Start Drawdown(1353.317psi)Start Buildup(1170.029psi)Last Buildup(1354.841psi)Mud After(1817.472psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 1200 1300 1400 1500 1600 1700 1800 0 10 20 90.05 90.10 90.15 90.20 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 59 3.25.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1354.841 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1354.841 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:80 Probe MD:4131.96ft Probe TVD:3823.52ft Delta Time 10 0 10 1 10 2 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1180 1200 1220 1240 1260 1280 1300 1320 1340 1360 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1180 1200 1220 1240 1260 1280 1300 1320 1340 1360 Radial Pressure(psi) 2015-09-20 60 3.26 ConPr_R01_Sta051_XPT 4111.96 ft MD 3.26.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : Drawdown Mobility: Mud Pressure Before: 1807.849 (psi) Mud Pressure After: 1808.043 (psi) Temperature Before: 90.15 (degF) Temperature After: 90.29 (degF) Pretest Rate: Pretest Volume: Comments: Pressure vs. Time Plot Run No:Run 1A Test No:83 Probe MD:4111.96ft Probe TVD:3803.52ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta051_XPT Swanson River Unit 213-15 Mud Before(1807.849psi)Start Drawdown(459.488psi)Mud After(1808.043psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 400 600 800 1000 1200 1400 1600 1800 0 10 20 89.9 90.0 90.1 90.2 90.3 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 61 3.27 ConPr_R01_Sta056_XPT 4046.99 ft MD 3.27.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : Drawdown Mobility: Mud Pressure Before: 1777.241 (psi) Mud Pressure After: 1777.291 (psi) Temperature Before: 90.01 (degF) Temperature After: 90.12 (degF) Pretest Rate: Pretest Volume: Comments: Pressure vs. Time Plot Run No:Run 1A Test No:89 Probe MD:4046.99ft Probe TVD:3738.56ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta056_XPT Swanson River Unit 213-15 Mud Before(1777.241psi)Start Drawdown(462.504psi)Mud After(1777.291psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 400 600 800 1000 1200 1400 1600 1800 0 5 10 15 89.8 89.9 90.0 90.1 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 62 3.28 ConPr_R01_Sta057_XPT 4048 ft MD 3.28.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Tight Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: Last Read Buildup Pressure : 393.688 (psi) Drawdown Mobility: Mud Pressure Before: 1777.428 (psi) Mud Pressure After: 1777.831 (psi) Temperature Before: 89.99 (degF) Temperature After: 90.04 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 10.05 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:90 Probe MD:4048ft Probe TVD:3739.57ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta057_XPT Swanson River Unit 213-15 Mud Before(1777.428psi)Start Drawdown(1803.378psi)Start Buildup(366.57psi)Last Buildup(393.688psi)Mud After(1777.831psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 400 600 800 1000 1200 1400 1600 1800 0 5 10 89.7 89.8 89.9 90.0 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 63 3.29 ConPr_R01_Sta059_XPT 3526.98 ft MD 3.29.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1247.625 (psi) Last Read Buildup Pressure : 1247.625 (psi) Drawdown Mobility: 6.27 (mD/cP) Mud Pressure Before: 1529.751 (psi) Mud Pressure After: 1529.969 (psi) Temperature Before: 88.19 (degF) Temperature After: 87.63 (degF) Pretest Rate: 0.94 (cm3/s) Pretest Volume: 9.87 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:93 Probe MD:3526.98ft Probe TVD:3218.6ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta059_XPT Swanson River Unit 213-15 Mud Before(1529.751psi)Start Drawdown(1247.615psi)Start Buildup(1238.941psi)Last Buildup(1247.625psi)Mud After(1529.969psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 1250 1300 1350 1400 1450 1500 1550 0 10 20 87.6 87.7 87.8 87.9 88.0 88.1 88.2 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 64 3.29.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1247.625 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1247.625 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:93 Probe MD:3526.98ft Probe TVD:3218.6ft Delta Time 10 0 10 1 10 2 -210 -110 010 110 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 1242.0 1242.5 1243.0 1243.5 1244.0 1244.5 1245.0 1245.5 1246.0 1246.5 1247.0 1247.5 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 1242.0 1242.5 1243.0 1243.5 1244.0 1244.5 1245.0 1245.5 1246.0 1246.5 1247.0 1247.5 Radial Pressure(psi) 2015-09-20 65 3.30 ConPr_R01_Sta065_XPT 2846.93 ft MD 3.30.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1014.794 (psi) Last Read Buildup Pressure : 1014.794 (psi) Drawdown Mobility: 14.76 (mD/cP) Mud Pressure Before: 1213.911 (psi) Mud Pressure After: 1214.256 (psi) Temperature Before: 81.52 (degF) Temperature After: 80.68 (degF) Pretest Rate: 0.87 (cm3/s) Pretest Volume: 4.68 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:101 Probe MD:2846.93ft Probe TVD:2551.79ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta065_XPT Swanson River Unit 213-15 Mud Before(1213.911psi)Start Drawdown(1014.883psi)Start Buildup(1011.92psi)Last Buildup(1014.794psi)Mud After(1214.256psi) p s i c m 3 d e g F ETIM_XPT (min) 0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 1000 1020 1040 1060 1080 1100 1120 1140 1160 1180 1200 1220 0 10 20 80.8 81.0 81.2 81.4 81.6 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 66 3.30.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1014.794 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1014.794 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:101 Probe MD:2846.93ft Probe TVD:2551.79ft Delta Time 10 0 10 1 10 2 -410 -310 -210 -110 010 110 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.0 0.5 0 1013.4 1013.6 1013.8 1014.0 1014.2 1014.4 1014.6 1014.8 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.0 0.5 0 1013.4 1013.6 1013.8 1014.0 1014.2 1014.4 1014.6 1014.8 Radial Pressure(psi) 2015-09-20 67 3.31 ConPr_R01_Sta071_XPT 2791.45 ft MD 3.31.1 Pressure vs. Time Plot Tool Type: XPT Pretest Type: Volumetric Drawdown Pretest Pretest Status: Valid Test Packer/Probe Type: Standard packer Primary Gauge: QCP Formation Pressure: 1005.247 (psi) Last Read Buildup Pressure : 1005.247 (psi) Drawdown Mobility: 0.24 (mD/cP) Mud Pressure Before: 1189.613 (psi) Mud Pressure After: 1191.36 (psi) Temperature Before: 79.43 (degF) Temperature After: 78.71 (degF) Pretest Rate: 0.49 (cm3/s) Pretest Volume: 9.88 (cm3) Comments: Pressure vs. Time Plot Run No:Run 1A Test No:108 Probe MD:2791.45ft Probe TVD:2500.48ft 18-Sep-2015 Hilcorp Alaska LLC Swanson River Unit ConPr_R01_Sta071_XPT Swanson River Unit 213-15 Mud Before(1189.613psi)Start Drawdown(1004.853psi)Start Buildup(914.567psi)Last Buildup(1005.247psi)Mud After(1191.36psi) p s i c m 3 d e g F ETIM_XPT (min) 0 1 2 3 4 5 6 7 8 9 10 11 12 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 0 10 20 30 78.8 79.0 79.2 79.4 QCP(psi), CQG Pressure with Dynamic Compensation CP_HYD(psi), Hydrostatic Sapphire Pressure with Dynamic Compensation PTV_XPT(cm3), XPT Pretest Volume MTEP_QG(degF), CQG Manometer Temperature 2015-09-20 68 3.31.2 FRID, Spherical and Radial Specialized Plots Last Buildup Pressure: 1005.247 (psi) Extrapolated Pressure: Buildup Mobility: Spherical Slope: Actual Spherical Slope on Spherical Derivative: Ideal Slope: 0 Actual Spherical Slope on Radial Derivative: Ideal Slope: -0.5 Actual Radial Slope on Spherical Derivative: Ideal Slope: 0.5 Last Buildup Pressure: 1005.247 (psi) Extrapolated Pressure: Actual Radial Slope on Radial Derivative: Ideal Slope: 0 Horizontal Mobility Thickness: Radial Slope: Flow Regime ID Plot Run No:Run 1A Test No:108 Probe MD:2791.45ft Probe TVD:2500.48ft Delta Time 10 0 10 1 10 2 110 210 Spherical Derivative(psi√s)Radial Derivative Spherical Specialized Plot Spherical Time Function 1.5 1.0 0.5 0 920 930 940 950 960 970 980 990 1000 Spherical Pressure(psi) Radial Specialized Plot Radial Time Function 1.5 1.0 0.5 0 920 930 940 950 960 970 980 990 1000 Radial Pressure(psi) 2015-09-20 69 1.Contents 5.5 Parameter Listing 2.Run 1A 6.Run 1A 2.1 Integration Summary 6.1 Integration Summary 2.2 Software Version 6.2 Software Version 2.3 Composite Summary 6.3 Composite Summary 2.4 Log ( EDTCB GR )6.4 Log ( EDTCB GR ) 2.5 Parameter Listing 6.5 Parameter Listing 3.Run 1A 7.Run 1A 3.1 Integration Summary 7.1 Integration Summary 3.2 Software Version 7.2 Software Version 3.3 Composite Summary 7.3 Composite Summary 3.4 Log ( EDTCB GR )7.4 Log ( EDTCB GR ) 3.5 Parameter Listing 7.5 Parameter Listing 4.Run 1A 8.Run 1A 4.1 Integration Summary 8.1 Integration Summary 4.2 Software Version 8.2 Software Version 4.3 Composite Summary 8.3 Composite Summary 4.4 Log ( EDTCB GR )8.4 Log ( EDTCB GR ) 4.5 Parameter Listing 8.5 Parameter Listing 5.Run 1A 5.1 Integration Summary 5.2 Software Version 5.3 Composite Summary 5.4 Log ( EDTCB GR ) Maxwell 5.1.33858.3100 Run 1A Log[4]:Up Up 3994.03 ft 4071.48 ft 17-Sep-2015 8:43:30 PM 17-Sep-2015 8:45:42 PM ON 0.00 ft No All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[4]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:52 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 3970 3980 3990 4010 4020 4030 4040 4060 4070 4000 4050 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:52 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS Maxwell 5.1.33858.3100 Run 1A Log[5]:Up Up 3690.10 ft 3731.33 ft 17-Sep-2015 9:30:04 PM 17-Sep-2015 9:31:39 PM ON 0.00 ft No 9:30:04 PM 9:31:39 PM All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[5]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:53 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 3660 3670 3680 3690 3710 3720 3730 3700 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:53 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS Maxwell 5.1.33858.3100 Run 1A Log[7]:Up Up 3469.98 ft 3524.06 ft 17-Sep-2015 10:12:17 PM 17-Sep-2015 10:14:31 PM ON 0.00 ft No All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[7]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:54 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 3440 3460 3470 3480 3490 3510 3520 3450 3500 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:54 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS Maxwell 5.1.33858.3100 Run 1A Log[9]:Up Up 3284.98 ft 3379.89 ft 17-Sep-2015 11:26:51 PM 17-Sep-2015 11:30:11 PM ON 0.00 ft No All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[9]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:54 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 3260 3270 3280 3290 3310 3320 3330 3340 3300 3360 3370 3380 3350 GHD GR_EDTC ECGR_EDTC RHGR_EDTC Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:54 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS Maxwell 5.1.33858.3100 Run 1A Log[13]:Up Up 4256.86 ft 4400.57 ft 18-Sep-2015 1:07:56 AM 18-Sep-2015 1:12:08 AM ON 0.00 ft No All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[13]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:55 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 0 150gAPI 0 150gAPI 4230 4240 4260 4270 4280 4290 4310 4320 4330 4340 4360 4370 4380 4390 4250 4300 4350 4400 GHD GR_EDTC ECGR_EDTC RHGR_EDTC Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:55 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS Maxwell 5.1.33858.3100 Run 1A Log[14]:Up Up 3512.12 ft 4048.06 ft 18-Sep-2015 2:49:11 AM 18-Sep-2015 3:05:09 AM ON 0.00 ft No All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[14]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:56 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 3490 3510 3520 3530 3540 3560 3500 3550 3560 3570 3580 3590 3610 3620 3630 3640 3660 3670 3680 3690 3710 3720 3730 3740 3760 3770 3780 3600 3650 3700 3750 GHD GR_EDTC ECGR_EDTC RHGR_EDTC 3780 3790 3810 3820 3830 3840 3860 3870 3880 3890 3910 3920 3930 3940 3960 3970 3980 3990 3800 3850 3900 3950 4000 GHD GR_EDTC ECGR_EDTC RHGR_EDTC 4010 4020 4030 4040 4000 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:56 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS Maxwell 5.1.33858.3100 Run 1A Log[16]:Up Up 2960.36 ft 3000.73 ft 18-Sep-2015 3:23:11 AM 18-Sep-2015 3:24:30 AM ON 0.00 ft No All depths are referenced to toolstring zero Company:Hilcorp Alaska, LLC Well:Swanson River Unit 213-15 Run 1A: Log[16]:Up:S003 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:57 Borehole Diameter (GHD) 6 16in TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI 6 16in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI 2930 2940 2960 2970 2980 2990 2950 3000 Description: DEPTH Domain Log for EDTCB GR channels Format: Log ( EDTCB GR ) Index Scale: 5 in per 100 ft Index Unit: ft Index Type: Measured Depth Creation Date: 20-Sep-2015 09:10:57 Borehole Diameter (GHD) 61 6in Calibrated Gamma Ray (GR_EDTC) EDTC-B 0 150gAPI TIME_1900 - Time Marked every 60.00 (s) Gamma Ray (ECGR_EDTC) EDTC-B 0 150gAPI Raw Gamma Ray (RHGR_EDTC) EDTC-B 0 150gAPI Run 1A: Parameters Barite Mud Presence FlagISSBAR Borehole No Borehole Status (Open or Cased Hole)BHS Borehole Open Bit SizeBS WLSESSION 6.75 in Casing Bottom (Logger)CBLO WLSESSION 2520 ft Cement DensityCDEN EDTC-B 2 g/cm3 Drilling Fluid DensityDFD Borehole 9.1 lbm/gal Generalized Caliper Selection for WL Log Down PassesGCSE_DOWN_PASS Borehole BS Generalized Caliper Selection for WL Log Up PassesGCSE_UP_PASS Borehole BS