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215-015
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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Cement Annulus, N2 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 11,200 feet N/A feet true vertical 7,584 feet N/A feet Effective Depth measured 11,074 feet 6,563 feet true vertical 7,439 feet 3,197 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 6,563' MD 3,197' TVD Packers and SSSV (type, measured and true vertical depth) ZXP LTP; N/A 6,563' ME 3,197' 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: Scott Warner, Operations Engineer 324-304 Sr Pet Eng: 7,500psi 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 N/A scott.warner@hilcorp.com 907-564-4506 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 1 Size 110' 0 10 0 5000 0 measured TVD 8,430psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-015 50-133-20548-00-00 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: ADL0389737|FEE-Private Ninilchik / Beluga-Tyonek Gas / Beluga Undefined Blossom 1 Plugs Junk measured Length Production Liner 6,785' 4,635' Casing Structural 3,406' 4-1/2" 6,785' 11,198' 7,555' 110'Conductor Surface Intermediate 16" 10-3/4" 110' 2,495' 4,790psi 5,210psi 6,890psi 2,495' 1,586' Burst Collapse 2,470psi p k ft t Fra O s 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 8:57 am, Nov 12, 2024 Page 1/2 Well Name: NINU Blossom 01 Report Printed: 11/6/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:8/29/2024 End Date: Report Number 1 Report Start Date 8/29/2024 Report End Date 8/30/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up Equipment, Nipple up BOPE's, Pressure test 250/3000 psi, Secure well for the night. Report Number 2 Report Start Date 8/30/2024 Report End Date 8/31/2024 Last 24hr Summary PJSM, Crew travel to location, Pick up injector & lube, Make up wash nozzle, Load reel & pressure test lube & stripper 250/3000 psi-pass, Run in hole with nozzle and load well with 19 bbls H20, Tag @ 10,511', Circulate hole clean, Batch mix & pump 59 bbls 15.3# cement slurry while pulling out of hole laying cement from 10,511' to 6600', Pull up to 6500' & circulate hole volume, Pull out of hole to surface, Secure well, Pump ball, Lay down lube & injector for the night Report Number 3 Report Start Date 8/31/2024 Report End Date 9/1/2024 Last 24hr Summary PJSM, Crew travel to location, Pick up READ memory CCL/GR, Run in hole & tag @ 6749, Flag pipe, Pull out of hole, Pick up tubing punch on coil, Run in hole & perf from 6550-6553, Pull out of hole while circulating down tubing and up IA, Lay down injection head & lube, Continue circulating 300 bbls total, Perform MIT @ 3079 psi lost 14 psi over 30 min-good, Secure well for the night. Report Number 4 Report Start Date 9/1/2024 Report End Date 9/2/2024 Last 24hr Summary PJSM, Crew travel to location, Break circulation down IA-good, Pump wiper ball to tank-good, Cut off & install YJ coil connector, Pull & pressure test-good, Pick up & make up 3.6" 1 run plug, Run in hole to 6490', Pressure up & load ball, Pump 34 bbls to seat & set retainer, Establish injectivity, PJSM, Batch mix 90 bbls, Swap to pump and fly mix 35 bbls 15.3# slurry, Pump 125 bbls of 15.3# cement total, Displace with 34 bbls water, Unsting and circulate 150 bbls water (15 bbls cmt contaminate), Pull out of hole, Lay down YJ tools, Trap 1700psi, Secure well, Pump wiper ball thru string, Rig down for the night Report Number 5 Report Start Date 9/2/2024 Report End Date 9/3/2024 Last 24hr Summary PJSM, Crew travel to location, Pick up injection head & lube, Pick up & make up READ CCL/GR/PRT/RBT, Run in hole, Log from 6400' to 1500' @ 30' min, Pull out out of hole, Pick up reverse nozzle, Run in hole, Tag @ 6450', Reverse hole with N2, Recovered 121 bbls, Pull out of hole, Rig down & release Fox energy. Report Number 6 Report Start Date 9/30/2024 Report End Date 10/1/2024 Last 24hr Summary PTW / PJSM w/ YJ E-line and Altus Intervention (Tractor). Well SI at 1910 psi (N2). MIRU, tractor, GR/CCL and 2-7/8" x 14' perf gun, move to well and PT 250 psi/3000 psi. Freefall to 1600', go on line with tractor to 5600' at ~20ft/min. Freefall and tag PBTD at 6430'. Draw down well to 1000 psi. Tie-in and perforate BEL-15 (6271'-6285'). No pressure build, flow back well to 750 psi and SI for overnight pressure build. Report Number 7 Report Start Date 10/1/2024 Report End Date 10/2/2024 Last 24hr Summary PTW/PJSM with YJ E-line and Altus tractor. SITP - 815 psi. Rig back on well and RIH w/ tractor and GPT. RIH to 1776', go on line with tractor to 5510'. Shut down tractor, RIH and locate fluid level at 5840' (431' above BEL-15 perfs). POOH, work suspended due to leaking wheel seals on both tractors. Call out Fox N2, PTW, RU and P-test lines 250 psi/3000 psi. Pump N2 at 800 scfm until well was pressured up to 2000 psi. SI and monitor pressure for 15 minutes. SITP 1950 psi. Secure well and RD N2 and E-line. Move to Pearl 11. Report Number 8 Report Start Date 10/3/2024 Report End Date 10/4/2024 Last 24hr Summary PTW/PJSM with YJ E-line and Altus tractor. SITP - 1096 psi. Rig back on well and RIH w/ tractor and GPT with CIBP in tandem. RIH to 1721', tractor engaged to 5500' (76 deg dev.), tractor off, power up GPT and locate fluid level at 6280' (BEL 15 - 6271'-6285'). Set CIBP at 6260'. M/U 10' gun with fluid sample catcher on bottom and perforate the Upr BEL 15 (6132'-6142'). SITP - 948 psi. No change after shots fired, draw down to 800 psi, still no change in pressure. Drop downhole with sample catcher and tag plug. No fluid was present in catcher tool. Secure well and rig back e-line. Report Number 9 Report Start Date 10/4/2024 Report End Date 10/5/2024 Last 24hr Summary PTW & PJSM with YJ E-line and Altus. SITP: 810 psi. Draw well down to 600 psi. Rig back on well and run with tractor, GPT and fluid sample bailer. Located fluid at 6140' (open perfs 6132'-6142'). Collected fluid sample and M/U 14' perf gun. RIH and perforate BEL 13 interval 6044'-6058'. No change in pressure. M/U GPT with CIBP in tandem, RIH, tractor down and locate fluid level at 5960. Correlate and set CIBP at 6030. Secure well and rig back e-line, SDFN. Report Number 10 Report Start Date 10/5/2024 Report End Date 10/6/2024 Last 24hr Summary PTW & PJSM with YJ E-line and Altus. Rig E-line back on well, M/U tractor, CCL and 3" x 25' cement dump bailer. SITP- 525 psi. Make 2 runs (5 gal/ea.) with 16# cement slurry using tractor conveyance and place on CIBP at 6030'. Approximate TOC - 6014'. Secure well and rig back e-line. Report Number 11 Report Start Date 10/6/2024 Report End Date 10/7/2024 Last 24hr Summary PTW & PJSM with YJ E-line and Altus. Rig E-line back on well, RIH w/ tractor and cement dump bailer filled with 6 gal. cement slurry, tractor through deviation and dump cement at 6014' to complete TOC target at 6005'. M/U 14' perf gun, GIH. PTW / PJSM with Fox N2. M/U hard line and PT 250/2500 psi. Pump N2 and pressure wellbore to 900 psi. Continue tractoring gun in hole and perforate the BEL 5 interval at 5824'-5838'. No pressure change. Draw down well to 850 psi, shut in. Secure well, rig back e-line. SDFN Field: Ninilchik Sundry #: 324-304 State: ALASKA Rig/Service:Permit to Drill (PTD) #:215-015Permit to Drill (PTD) #:215-015 Wellbore API/UWI:50-133-20648-00-00 Page 2/2 Well Name: NINU Blossom 01 Report Printed: 11/6/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 12 Report Start Date 10/7/2024 Report End Date 10/8/2024 Last 24hr Summary PTW & PJSM with YJ E-line and Altus. Rig E-line back on well, (SITP - 860 psi) RIH w/ tractor and 14' perf gun. Perforate the BEL 3A interval (5619'-5633'). No pressure increase. Draw well down in 200 psi increments, shut in for 15 minute pressure builds between draw downs, to 0 psi. No flow or LEL detected. Secure well and SDFN. Report Number 13 Report Start Date 10/8/2024 Report End Date 10/9/2024 Last 24hr Summary PTW & PJSM with YJ E-line, Altus and Fox N2. Rig E-line back on well. (SITP-87 psi). RIH with tractor and GPT with CIBP in tandem. Locate fluid level at 5210' (400' above BEL 3A perfs 5619'-33'). Roll on N2 and pressure up to 1650 psi. Log fluid level at 5655'. P/U and set CIBP at 5600'. RIH w/ 14' perf gun and perforate the BEL1A (5431'-5445'). Secure well and SDFN. Report Number 14 Report Start Date 10/9/2024 Report End Date 10/10/2024 Last 24hr Summary PTW/PJSM with YJ E-line and Baker (Altus). (789 psi SITP) RIH and perforate the BEL 1 interval 5367'-5377'. Gun wet, M/U GPT and CIBP, call out N2. RIH and locate fluid level at 4720', pump N2 to 1730 psi and chase fluid back to perfs at 5367'-77'. Tie-in CIBP and set at 5360'. Secure well and SDFN. Report Number 15 Report Start Date 10/10/2024 Report End Date 10/11/2024 Last 24hr Summary PTW/PJSM with YJ E-line and Baker (Altus). (1175 psi SITP) M/U tractor and 10' perf gun, tractor in hole, draw well down to 850 psi and perforate the BEL C interval 5301'-5311'. 2 psi pressure drop. Secure well, RDMO E-line. Flow back well in 200 psi increments, SI for 15 min. and record pressure builds. No flow, no LEL detected. Crystal gauge on record. Job complete. Field: Ninilchik Sundry #: 324-304 State: ALASKA Rig/Service: ___________________________________________________________________________________ Updated by DMA 11-07-24 SCHEMATIC Ninilchik Unit Well: Blossom #1 PTD: 215-015 API: 50-133-20648-00 PBTD =10,485 MD/ 6,908 TVD TD = 11,200 MD/ 7,584 TVD Max Deviation: 77 deg Max Dogleg: 6.6 deg/100 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16Conductor 84 X-56 Weld 15.010Surf 110 10-3/4"Surf. Csg 45.5 L-80 BTC 9.950Surf 2,495 7-5/8"Prod. Csg 29.7 L-80 BTC 6.875Surf 6,785 4-1/2"Prod Liner 12.6 L-80 DWC/C-HT 3.958"6,56311,198 TUBING DETAIL 4-1/2Tubing 12.6 L-80 BTC-mod 3.958Surf 6,563 16 10-3/4 4-1/2 JEWELRY DETAIL No. Depth ID OD Item 1 184.0006.750Tubing Hanger, 4-1/2 2 193.9584.500Pup Joint 3 2,0193.8136.5004-1/2 Chemical Injection Mandrel 4 5,360CIBP (10/9/24) 5 5,600CIBP (10/8/24) 6 6,030CIBP (10/4/24) w/25 cmt - TOC 6,005 (10/6/24) 7 6,260CIBP (10/3/24) 8 6,490N/A N/A Cement retainer (9/1/24) 9 6,550N/A N/A Tubing Punch 6,550-6,553 (8/31/24) 10 6,5633.9584.5004-1/2 Seal Assembly 11 6,5634.5006.500Liner Tie-Back Receptacle 12 6,5635.0006.672Liner Top Packer 13 10,485CIBP (8/31/2015) 7-5/8 7-5/8 TOC @ 2,000 1 2 3 10 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Date Size Status BEL C 5,301' 5,311' 2,271' 2,275' 10/10/24 2-7/8Open BEL 1 5,367' 5,377' 2,297' 2,301' 10/9/24 2-7/8Isolated BEL 1A 5,431' 5,445' 2,325' 2,332' 10/8/24 2-7/8Isolated BEL 3A 5,619' 5,633' 2,424' 2,433' 10/7/24 2-7/8Isolated BEL 5 5,824' 5,838' 2,558' 2,570' 10/6/24 2-7/8Isolated BEL 13 6,044' 6,058' 2,729' 2,741' 10/4/24 2-7/8Isolated BEL 15 6,132' 6,142' 2,802' 2,810' 10/3/24 2-7/8Isolated BEL 15 6,271' 6,285' 2,924' 2,937' 9/30/24 2-7/8Isolated BEL 132 8,345 8,365 4,893 4,912 9/4/15 2-7/8Isolated TY 4 8,844 8,874 5,365 5,393 9/3/15 2-7/8Isolated TY 8 9,440 9,448 5,923 5,931 10/20/15 2-7/8Isolated TY 13 9,900 9,930 6,356 6,384 9/2/15 2-7/8Isolated TY 19 10,324 10,340 6,757 6,772 9/1/15 2-7/8Isolated TY 19 10,392 10,408 6,821 6,836 10/19/15 2-7/8Isolated TY 20 10,492 10,512 6,915 6,934 8/3/15 2-7/8Isolated TY 20 10,536 10,561 6,956 6,980 8/2/15 2-7/8Isolated TY 20 10,580 10,610 6,988 7,026 8/2/15 2-7/8Isolated TY 20 10,582 10,612 6,990 7,028 8/27/15 2-7/8Isolated TY 42 10,971 10,986 7,368 7,382 8/1/15 2-7/8IsolatedRA Mkr Jt 10,697' RA Mkr Jt 10,203' RA Mkr Jt 9,984' RA Mkr Jt 8,780' RA Mkr Jt 8,207' 11 12 TY 20 TY 42 13 TY 19 TY 4 TY 13 BEL C TY 8 9 TOC @ ~2,200' 8 BEL 132 6 7 5 4 BEL 15 BEL 13/15 BEL 3/5 BEL 1 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: 9/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240912 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 7/22/2024 BAKER RPM Blossom 1 50133206480000 215015 8/31/2024 READ Coilflag Blossom 1 50133206480000 215015 9/2/2024 READ MemoryRadialCementBondLog KBY 43-07Y 50133206250000 214019 9/9/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 8/29/2024 AK E-LINE Perf NCIU A-19 50883201940000 224026 9/4/2024 AK E-LINE Plug/Perf NCIU A-20 50883201960000 224065 8/29/2024 AK E-LINE Perf NCIU A-20 50883201960000 224065 9/3/2024 AK E-LINE Plug/Perf PBU N-21A (REVISED) 50029213420100 196196 3/28/2024 BAKER SPN PBU N-02 50029200830000 170055 7/25/2024 BAKER SPN PBU S-104 50029229880000 200196 7/7/2024 BAKER SPN PBU Z-68 50029234930000 213093 7/6/2024 BAKER SPN Pearl 11 50133207120000 223032 6/24/2024 BAKER SPN Revision explanation: OmniView .las file was the same as the carbo/oxygen .las file, omniview file has been replaced with the correct file and data. Please include current contact information if different from above. T39545 T39546 T39546 T39547 T39548 T39548 T39549 T39549 T39550 T39551 T39552 T39553 T39554 Blossom 1 50133206480000 215015 8/31/2024 READ Coilflag Blossom 1 50133206480000 215015 9/2/2024 READ MemoryRadialCementBondLog Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.12 12:52:42 -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: Cement Annulus, 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? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,198'N/A Casing Collapse Structural Conductor Surface 2,470 psi Intermediate Production 4,790 psi Liner 7,500 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng ZXP Liner Top Packer; N/A 6,563' MD / 3,197' TVD; N/A 7,555'11,074'7,439' Ninilchik Beluga-Tyonek Gas 16" 10-3/4" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Blossom 1CO 701C Same/ Beluga Undefined 3,406'7-5/8" ~1004psi 6,785' N/A Length June 5, 2024 11,198'4,635' 4-1/2" 7,555' 6,785' Perforation Depth MD (ft): 4-1/2" See Attached Schematic 5,210 psi 110'110' 2,495' Size 110' 2,495' MD Hilcorp Alaska, LLC Proposed Pools: 12.6# / L-80 TVD Burst 6,563 6,890 psi 1,586' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0389737|FEE-Private 215-015 50-133-20548-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY 8,430 psi Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: m n P s 66 t N W Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:07 pm, May 22, 2024 Digitally signed by Jacob Flora (5220) DN: cn=Jacob Flora (5220) Date: 2024.05.22 13:20:45 - 08'00' Jacob Flora (5220) 324-304 7,584 * * Per Well Completion Report dated 11/2/2015 SFD DSR-5/22/24SFD 5/23/2024 Beluga Undefined Perforate 11,200' * CT BOP test to 3000 psi Place cement plug between Beluga-Tyonek Gas Pool and Beluga Undefined Gas pool, unless there is potential for future production from the Bel-Tyo Gas Pool. Pools will need to be isolated from one another per 20 AAC 25.112(c) before final abandonment.10-404 X Perform MIT-IA to 1500 psi within 30 days after shooting final set of perforations. Submit CBL to AOGCC and obtain approval before perforating. BJM 6/4/24*&:JLC 6/4/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.04 15:47:25 -08'00'06/04/24 20648 JSB RBDMS JSB 060624 Blossom 1 Cement Annulus Well Name: Blossom 1 API Number: 50-133-20648-00-00 Current Status: Offline Gas Well Permit to Drill Number: 215-015 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 299-4824 (C) Maximum Expected BHP before plug back: 3,174 psi @ 7382’ TVD (0.43 psi/ft gradient at TD) Maximum Expected BHP after plug back: 1,308 psi @ 3043’ TVD (0.43 psi/ft gradient at TD) MPSP with new perfs: 1,004 psi (BHP minus 0.1 psi/ft gradient) Applicable Frac Gradient: 0.63 psi/ft using 12.1 ppg EMW FIT at the surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.63-0.1) = 1004 psi / 0.53 = 1895 ‘ TVD Top of Applicable Gas Pool: 5877’ MD/ 2598’ TVD Well History: Blossom #1 is a grass roots well that was completed in 2015. The well consists of 10-3/4” surface casing and 7- 5/8” production casing with 4-1/2” liner/liner top packer and 4-1/2” tie-back tubing. Multiple intervals were tested after drilling and commercial gas was never found in the lower section of the liner. The goal of this sundry is to plugback the lower Beluga and Tyonek, pump a cement annulus isolation job and perforate the upper Beluga. All existing and proposed perfs below 5877’ MD are in the Beluga Gas Pool/PA and If gas is proven to be commercial, Hilcorp will request commingling above the Beluga Gas Pool/PA with sand in the Beluga Undefined Pool. Notes Regarding Wellbore Condition x Inclination o > 70° inclination starting at ~1700’ MD, max dog leg 6.6°/100 @ 1681’ MD. o Sail angle of 74°- 77° from 1700’ to 5274’ MD, then rolls over to 20° by PBTD o Able to free fall from ~5500’ MD to PBTD during prior tractor operations o 7-5/8” x 4-1/2” Annulus has 172 bbls of corrosion inhibitor water in it Coil Tubing Lower Beluga/Tyonek Plug Back Procedure 1. MIRU CTU, 24hr notice for BOP test 2. Conduct BOP test to 250psi Low / 3500psi High 3. RIH with circ nozzle, fill well using fresh water (8.4 ppg) and tag bottom. Wash to CIBP at 10,485’. Circ bottoms up 4. RU cement unit, PT lines 5. Mix and pump 59 bbls of cement (when cement hits nozzle start POOH laying cement in 1 for 1) 6. POOH to 6500’ and circ bottoms up o Note any cement in returns 7. Wait on cement 8. RIH w/Memory GR/CCL and tag cement plug. o Place 4000# of coil weight on plug (Est TOC is 6600’, top of plug must be atleast 100’ above top perf @ 8345’) o Flag coil in general vicinity of planned tubing punch at 6,550, POOH o Record the coiled tubing electronic counter reading and mechanical counter reading at flag depth perfs below 5877’ MD are in the Beluga Gas Pool/ Beluga-Tyonek Gas Pool SFD 5877’ MDTop of Applicable Gas Pool , equivalent to 3,730' MD. SFD Blossom 1 Cement Annulus 4-1/2” x 7-5/8” Prep for IA Cementing Procedure 9. MU and RIH with tubing punch 10. Shoot tubing punch at ±6,550’ MD (~13ft above packer at 6563), POOH o Correct depth at flag from previously run GR/CCL log prior to shooting tubing punch. Reset the electronic depth counter to read the corrected measured depth. 11. Establish circulation from tubing to IA o Repeat tubing punch ~50ft shallower if circulation isn’t established 12. Once circulation is established in both directions, circulate a minimum of 300 bbls of 8.4 ppg fluid (until returns are clean): o IA volume = ~172 bbls i. 4-1/2” x 7-5/8” = 0.0262 x 6,550 ft = ~172 bbls o Tubing volume = 0.0152 bbl/ft x 6,550ft = ~100 bbls 13. CMIT-TxIA to 2500psi (no chart required) – ensure tubing punch did not rupture casing 4-1/2” x 7-5/8” IA Cementing Procedure 14. RIH with 4-1/2” one trip cement retainer and set @ 6490’, establish circulation up 4-1/2” x 7-5/8” annulus o Note: annulus was already circulated post tubing punch and this is to ensure there is circulation through the retainer/TxIA 15. RU cement truck, PT lines to 250psi low / 3,000psi high 16. Mix and pump ~15.3ppg cement down the coil, taking returns up the 4-1/2” x 7-5/8” IA 17. Planned TOC in IA is ±2,200’ MD. (±114 bbls required) o 0.0262bbl/ft x 4350ft =114 bbls 18. Displace to cement retainer with 35 bbls (coil volume) of fresh water 19. Unstab coil from retainer, cleanout above retainer as needed 20. Test cement retainer float (check valve) o If necessary/check valve fails, trap pressure on the tubing (~610 psi) with annulus pressure at 0 psi to ensure cement doesn’t u-tube o Flag coil above retainer set depth for reference when running CBL to ensure we do not tag bottom due to CBL compression limitations and to be used as depth control during perforating 21. RDMO cementers 22. POOH with coil 23. Wait minimum of 24hrs on cement 24. RIH with coil tubing and tag retainer with a nozzle to drift tubing for CBL/perf guns o Verify flag is accurate for upcoming CBL/perforating. 25. RIH with CBL and CCL/GR memory tools and complete CBL. (submit CBL to AOGCC and obtain approval before perforating) o Log from top of retainer flag depth to 1500’. Estimated TOC is 2200’ 26. MIT-IA to 1500 psi for 30 charted minutes 27. MIT-T to 1500 psi for 30 charted minutes 28. RIH with coil tubing and reverse lift water from wellbore (recover ~100 bbls) Blossom 1 Cement Annulus 29. Trap N2 pressure on tubing per OE/RE recommendation for perforating, ~1000 psi (25% underbalanced) Coil Tubing/Eline Perf Procedure 30. MIRU Coil Tubing or Eline Tractor and pressure control equipment 31. PT lubricator to 250psi low / 3000 psi High 32. RIH and perforate as directed by reservoir team. Plan to flow test each interval prior to moving up hole which may include GPT logs to verify if zone was wet. See following step for testing procedure Sand Top MD Btm MD TopTVD Btm TVD Interval BEL C ±5,017' ±5,033' ±2,191' ±2,195' ±16' BEL C ±5,301' ±5,311' ±2,271' ±2,275' ±10' BEL 1 ±5,367' ±5,376' ±2,297' ±2,300' ±09' BEL 1A ±5,431' ±5,444' ±2,325' ±2,331' ±13' BEL 3A ±5,620' ±5,631' ±2,425' ±2,432' ±11' BEL 5 ±5,829' ±5,838' ±2,563' ±2,570' ±09' BEL 13 ±6,044' ±6,052' ±2,729' ±2,735' ±08' BEL 15 ±6,132' ±6,142' ±2,802' ±2,810' ±10' BEL 15 ±6,272' ±6,283' ±2,925' ±2,935' ±11' a. Proposed perfs are also shown on the proposed schematic in red font. b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation. c. If perforating on Eline, use Gamma/CCL to correlate or flag depths from CBL if using coil. d. Record tubing pressures before and after each perforating run at 5 min., 10 min. and 15 min intervals post shot and record. e. Sands below 5877’MD/2598’TVD are in the Ninilchik Beluga/Tyonek Gas Pool per CO 701C. If gas is proven to be commercial, Hilcorp will request commingling with sand in the Beluga Undefined Pool. 33. Intervals will be tested with the following procedure: Bleed N2 off following these directions: a. Bleed N2 off ~ 5 psi/min down 200 psi b. SI for 15 min see if any build (take readings every 5 min) c. Bleed N2 off ~ 5 psi/min another 200 psi d. SI for 15 min see any build (take readings every 5 min) e. If unable to bleed well down slowly bleed until methane at surface (using LEL detector) f. SI well when methane is at surface i. MIRU well test equipment, expect 1 week to get equipment set up with flare (see procedure below for testing gas with flare) g. If well continues to bleed without methane buildup, drawdown well at same rate ~ 5 psi/min in 200 psi increments to 0 psi with 15 min pressure builds and shut-in overnight for buildup, leaving Crystal gauge on well to monitor buildup h. Notify engineer of pressure build data in the morning for next steps 34. Check for water inflow with Coil/Eline PT tools. i. If zone produces water with no sustained gas Set CIBP within 50ft of top perf. ii. Use Nitrogen to push water back prior to setting plug, if water is above next zone to test. Dump bail 25 ft of cement on top of CIBP that is set above the last set of Beluga-Tyonek gas pool perfs to isolate from the Beluga Undefined gas Pool if there is no potential for producing from Beluga-Tyonek. -bjm Blossom 1 Cement Annulus Gas Success Test plan with Flare 35. MIRU test equipment 36. Flow well at rates between 100mcf -7000 mscf (design limits of equipment) – it is not expected that rates will be much more than 2 mmscfd for these zones, but we are being optimistic 37. Continue testing gas sands following steps above if sand is gas or follow steps below if sand is found to be wet. Post-Perf MIT-IA 38. Perform MIT-IA to 1500 psi once job is complete and well has been brought online within 30 days. Gas Sand Failure Case (If any zone produces sand and/or water or needs isolated and/or cleanout): Coil Tubing Procedure (Contingency) 1. MIRU Coil equipment (provide 24hr notice as necessary for BOP witness) 2. Test BOPs to 3,000 psi High/250 psi Low 3. Coil run memory PT to find fluid level 4. Use N2 to push fluid below perfs (verify fluid depth with PT tool) 5. PU 4-1/2” CIBP or 4-1/2” patch a. If a CIBP is set (it must be set within 50ft of the top perf being plugged back) 6. If necessary to cleanout or unload well with coiled tubing, a. MIRU coil equipment (provide 24hr notice as necessary for BOP witness) b. Test BOPs, 3,000 psi High/ 250 psi Low c. Cleanout using water & N2 d. Blow well dry with coil using N2. Eline Tractor Procedure (Contingency) 1. MIRU Eline and tractor 2. Pressure test equipment to 3,000 psi High/250 psi Low 3. Eline run PT to find fluid level 4. Use N2 or Gas Lift to push fluid below perfs (verify fluid depth with PT tool) 5. PU 4-1/2” CIBP, or 4-1/2”patch Attachments: 1. Current schematic 2. Proposed Schematic 3. Standard Well procedure – N2 Operations 4. Fox BOP Schematic Place cement plug between Beluga-Tyonek Gas Pool and Beluga Undefined Gas pool, unless there is potential for future production from the Bel-Tyo Gas Pool. Pools will need to be isolated from one another per 20 AAC 25.112(c) before final abandonment. -bjm 38.Perform MIT-IA to 1500 psi once job is complete and well has been brought online within 30 days. ___________________________________________________________________________________ Updated by SRW 05-02-24 CURRENT SCHEMATIC Ninilchik Unit Well: Blossom #1 PTD: 215-015 API: 50-133-20648-00 PBTD =10,485’ MD/ 6,908’ TVD TD = 11,200’ MD/ 7,584’ TVD Max Deviation: 77 deg Max Dogleg: 6.6 deg/100 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor 84 X-56 Weld 15.010”Surf 110’ 10-3/4"Surf. Csg 45.5 L-80 BTC 9.950”Surf 2,495’ 7-5/8"Prod. Csg 29.7 L-80 BTC 6.875”Surf 6,785’ 4-1/2"Prod Liner 12.6 L-80 DWC/C-HT 3.958"6,563’11,198’ TUBING DETAIL 4-1/2”Tubing 12.6 L-80 BTC-mod 3.958”Surf 6,563’ 16” 10-3/4” 4-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 18’4.000”6.750”Tubing Hanger, 4-1/2” 2 19’3.958”4.500”Pup Joint 3 2,019’3.813”6.500”4-1/2” Chemical Injection Mandrel 4 6,563’3.958”4.500”4-1/2” Seal Assembly 5 6,563’4.500”6.500”Liner Tie-Back Receptacle 6 6,563’5.000”6.672”Liner Top Packer 7 10,485’CIBP (8/31/2015) 7-5/8” Shoe @ 6,785’ Shoe @ 11,198’ -6-3/4” hole TOC @ 2,000’ 1 2 3 4 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Date Size Status BEL 132 8,345 8,365 4,893 4,912 9/4/15 2-7/8”Open TY 4 8,844 8,874 5,365 5,393 9/3/15 2-7/8”Open TY 8 9,440 9,448 5,923 5,931 10/20/15 2-7/8”Open TY 13 9,900 9,930 6,356 6,384 9/2/15 2-7/8”Open TY 19 10,324 10,340 6,757 6,772 9/1/15 2-7/8”Open TY 19 10,392 10,408 6,821 6,836 10/19/15 2-7/8”Open TY 20 10,492 10,512 6,915 6,934 8/3/15 2-7/8”Isolated TY 20 10,536 10,561 6,956 6,980 8/2/15 2-7/8”Isolated TY 20 10,580 10,610 6,988 7,026 8/2/15 2-7/8”Isolated TY 20 10,582 10,612 6,990 7,028 8/27/15 2-7/8”Isolated TY 42 10,971 10,986 7,368 7,382 8/1/15 2-7/8”Isolated RA Mkr Jt 10,697' RA Mkr Jt 10,203' RA Mkr Jt 9,984' RA Mkr Jt 8,780' RA Mkr Jt 8,207' 5 6 TY 20 TY 42 7 TY 19 TY 4 TY 13 BEL 132 TY 8 TY 19 ___________________________________________________________________________________ Updated by SRW 05 /02/24 PROPOSED Ninilchik Unit Well: Blossom #1 PTD: 215-015 API: 50-133-20648-00 PBTD =10,485’ MD/ 6,908’ TVD TD = 11,200’ MD/ 7,584’ TVD Max Deviation: 77 deg Max Dogleg: 6.6 deg/100 CASING DETAIL Size Type Wt Grade Conn.ID Top Btm 16”Conductor 84 X-56 Weld 15.010”Surf 110’ 10-3/4"Surf. Csg 45.5 L-80 BTC 9.950”Surf 2,495’ 7-5/8"Prod. Csg 29.7 L-80 BTC 6.875”Surf 6,785’ 4-1/2"Prod Liner 12.6 L-80 DWC/C-HT 3.958"6,563’11,198’ TUBING DETAIL 4-1/2”Tubing 12.6 L-80 BTC-mod 3.958”Surf 6,563’ 16” 10-3/4” 4-1/2” JEWELRY DETAIL No.Depth ID OD Item 1 18’4.000”6.750”Tubing Hanger, 4-1/2” 2 19’3.958”4.500”Pup Joint 3 2,019’3.813”6.500”4-1/2” Chemical Injection Mandrel 4 6,490’N/A N/A Cement retainer 5 6,550’N/A N/A Tubing Punch 6 6,563’3.958”4.500”4-1/2” Seal Assembly 7 6,563’4.500”6.500”Liner Tie-Back Receptacle 8 6,563’5.000”6.672”Liner Top Packer 9 10,485’CIBP (8/31/2015) 7-5/8” Shoe @ 6,785’ Shoe @ 11,198’ -6-3/4” hole 7-5/8” TOC @ 2,000’ 1 2 3 6 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Date Size Status BEL C ±5,017'±5,033'±2,191'±2,195'Proposed 2-7/8”TBD BEL C ±5,301'±5,311'±2,271'±2,275'Proposed 2-7/8”TBD BEL 1 ±5,367'±5,376'±2,297'±2,300'Proposed 2-7/8”TBD BEL 1A ±5,431'±5,444'±2,325'±2,331'Proposed 2-7/8”TBD BEL 3A ±5,620'±5,631'±2,425'±2,432'Proposed 2-7/8”TBD BEL 5 ±5,829'±5,838'±2,563'±2,570'Proposed 2-7/8”TBD BEL 13 ±6,044'±6,052'±2,729'±2,735'Proposed 2-7/8”TBD BEL 15 ±6,132'±6,142'±2,802'±2,810'Proposed 2-7/8”TBD BEL 15 ±6,272'±6,283'±2,925'±2,935'Proposed 2-7/8”TBD BEL 132 8,345 8,365 4,893 4,912 9/4/15 2-7/8”Isolated TY 4 8,844 8,874 5,365 5,393 9/3/15 2-7/8”Isolated TY 8 9,440 9,448 5,923 5,931 10/20/15 2-7/8”Isolated TY 13 9,900 9,930 6,356 6,384 9/2/15 2-7/8”Isolated TY 19 10,324 10,340 6,757 6,772 9/1/15 2-7/8”Isolated TY 19 10,392 10,408 6,821 6,836 10/19/15 2-7/8”Isolated TY 20 10,492 10,512 6,915 6,934 8/3/15 2-7/8”Isolated TY 20 10,536 10,561 6,956 6,980 8/2/15 2-7/8”Isolated TY 20 10,580 10,610 6,988 7,026 8/2/15 2-7/8”Isolated TY 20 10,582 10,612 6,990 7,028 8/27/15 2-7/8”Isolated TY 42 10,971 10,986 7,368 7,382 8/1/15 2-7/8”Isolated RA Mkr Jt 10,697' RA Mkr Jt 10,203' RA Mkr Jt 9,984' RA Mkr Jt 8,780' RA Mkr Jt 8,207' 7 8 TY 20 TY 42 9 TY 19 TY 4 TY 13 BEL C - BEL 15 TY 8 TY 19 5 Proposed TOC @ ~2,200' 4 BEL 132 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.) 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C U " 0 0 0 O U rn J •p w Q E I l to CU7 E V p a 'p o aoi y E E O m 0 0 0 0 m a o a) 0 o a) d E p Q a. 2 w w w j3 z U a 0 10 0 0 I 11 0 • ,,5_o,5 Seth Nolan Hilcorp Alaska, LSC - /� --77 cc,, GeoTech 3800 Centerpoint Drive, Suite 100 d�P T,/ Anchorage, AK 99503 Tele: 907 777-8308 rrirarp:uaMkn.1.1 I Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 02/01/16 To: Alaska Oil & Gas Conservation Commission Meredith Ghul Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 RECEIVED DATA TRANSMITTAL FEB 0 2 2016 Blossom 1 PB1 AOGCC Mudlog and CBL data Prints: SCMT-GR-CCL CD 1: LAS Data 2/1/20162:45 PM File folder 2(0(01-5 Log Data 2;1/20162:45 PM File folder w. Blossom 1 PB1 2MD DEL 2/1/2016 12:08 PM EMF File 23;970 KB ,jam Blossom 1 P812MD FEL 2/11201612:10 PM EMF File 2.,033 KB O.�QI�� Blossom 1 PB12MD GRL 2/1/2016 12:11 PM EMF File 20,21; KB Y 1r Z Blossom 1 PB1 5MD FEL 2111/201612:13 PM EMF File 32„357 KB 0(12 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 R ceive ,� Date: RFCEIVEL LLU 05 2016 AOGCC • • Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday, February 02, 2016 3:35 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: Blossom 1 (PTD 215-015): Surface Location Question Ok. After review it was discovered that the original PTD was submitted with the As-Staked location (1155' FSL, 373.7' FEL). After the conductor was driven and the well was drilled, we obtained the As-Built survey location (1059' FSL, 379' FEL) from McLane and submitted the As-Built with the 10-407. So, the 10-407 has the correct numbers and the PTD is incorrect. It looks like this well got ushed up on our schedule and we were rushing to get it permitted in time, to not have the rig waiting idle for a permiHowever, this may have been one of the last wells ever submitted in this fashion. After some discussion with the AOGCC and realizing how big of a headache it was causing everyone to try and keep this straight, we quit submitting PTD's in this fashion. All PTD's going forward have been submitted after the conductor pipe has been set and surveyed. We strive for excellence in the drilling department and brought this issue up with our asset teams, to ensure we gave ourselves plenty of time to get the correct information to submit, by locking down our drilling schedule and not allowing it to be modified within a 60 day window of drilling a well. It appears that this particular well went un-noticed as to the differences in SHL until now, and was never communicated directly to the AOGCC prior to drilling. Please advise on how to proceed. And let me know if you have any additional questions. Thank you! -, lu r�c�r�= '7-; 7(-(= 4" ‘Fix Monty M Myers /1?"-er Z-C) rt�� Drilling Engineer 10-e.1o-pt— Z Hilcorp Alaska Office: 907.777.8431 Z f6 -�� Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, February 02, 2016 2:10 PM To: Monty Myers Subject: Blossom 1 (PTD 215-015): Surface Location Question Monty, While reviewing the Blossom 1 file, I noticed that the surface location coordinates presented on the Completion Report are about 100' different from those presented in the Permit to Drill application and on the as-staked survey plat. Which coordinates are correct? Please note that 20 AAC 25.015 (a)(1) requires the commission's approval of a new application for a Permit to Drill if the proposed surface location is changed. If the surface location was moved,did the AOGCC approve this change in advance? Please note that in this portion of the Kenai Peninsula, where land parcels are small and surface owners may not be the same as mineral interest owners, minor changes in location coordinates may have large impacts. 1 • • Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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.davies@alaska.gov. 2 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, February 02, 2016 2:10 PM To: Monty Myers (mmyers@hilcorp.com) Subject: Blossom 1 (PTD 215-015): Surface Location Question Monty, While reviewing the Blossom 1 file, I noticed that the surface location coordinates presented on the Completion Report are about 100'different from those presented in the Permit to Drill application and on the as-staked survey plat. Which coordinates are correct? Please note that 20 AAC 25.015 (a)(1) requires the commission's approval of a new application for a Permit to Drill if the proposed surface location is changed. If the surface location was moved, did the AOGCC approve this change in advance? Please note that in this portion of the Kenai Peninsula,where land parcels are small and surface owners may not be the same as mineral interest owners, minor changes in location coordinates may have large impacts. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 76 Avenue,Suite 100 Anchorage,AK 99501 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.davies@alaska.gov. 1 • • Schwartz, Gu L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, February 01, 2016 3:48 PM To: Schwartz, Guy L(DOA) Subject: FW: Blossom #1 (215-015) completion report Attachments: Blossom -1 Intermediate Post Job.pdf FYI Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Monty Myers Sent: Monday, February 01, 2016 3:18 PM To: 'Schwartz, Guy L(DOA)' Subject: RE: Blossom #1 (215-015) completion report Good afternoon guy. It looks like the volumes got reported incorrectly in quite a few different area.The total pumped should have been 185 bbls of lead and 54 bbls of tail. I'm not certain how the numbers got so skewed on our casing and cement report and the WellEZ reports. I will get those corrected. Also attached is the CBL for the 4-1/2" liner. It appears paper copies were never sent over. Meredith should be receiving paper and digital copies on Wednesday from our geo tech,Seth Nolan. Blossom never even made a hint of gas, so it was a huge disappointment even after the initial logs looked good.Just another duster! 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: Monday, February 01, 2016 10:09 AM To: Monty Myers Subject: Blossom #1 (215-015) completion report Monty, As per our phone call can you look at 7 5/8"cement report and verify what was pumped. Also,send me a PDF copy of the CBL that was run in the prod liner. Not sure if it was ever submitted to our office yet but am looking for it. 1 Has this well made any production y . • 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). 2 111, CS 11 Seth Nolan Hilcorp Alaska, LL ' GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 p ,� Cei Y�44 Ifilrnrp Alaska.id.t: Fax: 907 777-8510 "�` E-mail: snolan@hilcorp.com lV` DATE 12/18/15 c To: Alaska Oil & Gas Conservation Commission �ECEIVED Meredith-COMPGAKi DEC 2 2 2015 Petroleum Geology Assistant 333 W 7th Ave Ste 100 AOGCC Anchorage, AK AOGCC DATA TRANSMITTAL Blossom 1 PB1 Elog and Mudlog data CD 1: Blossom 1 PB1 FINAL LOGS 12/18/241510:009... File folder Blossom 1 PB1 LAS EXPORTS 12/18/2015 10:09... File folder 26214q. Hilcorp Blossom 1 Definitive Survey 12/18/20159:24 AM Adobe Acrobat D... 191 KB Please include current contact information if different from above. y� /V® ala l/ Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 t`Recei Date: RECEIVED EE:, 0 AOGCC RECEIVED 0 0 NOV 0 2 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION y! WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas E . SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development E . Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,�or 041 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 10/N/2015 . '215-015;315-354;315-435;315-572;315-495 3.Address: 7.Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 •5/24/2015 ' • 50-133-20648-00-00 - 4a.Location of Well(Governmental Section): 8. Date TD Reached: , 16.Well Name and Number: 7-'1- Surface: 1059'FSL,379'FEL,Sec 14,TIN,R13W,AK • 7/9)2015 '7•f s 2.1,...•1:• . Blossom#1 • Top of Productive Interval: 9.KB(ft above MSL): •23. 17.Field/Pool(s): 731'FSL,2266'FWL,Sec 11,Ti N, R13W,SM,AK(Top Perf Coordinates) GL(ft above MSL): •215 •Ninilchik/Beluga/Tyonek Gas Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 1612'FSL, 1931'FWL,Sec 11,TIN,R13W,SM,AK -10,485'MD/6,908'TVD - Fee Private Ninilchik Tract 3 ADL 389737 - 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 231709 • y-2258238 Zone- 4 .11,200'MD/7,584'TVD - N/A TPI: x- 229169 y-2263241 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 228854 y-2264130 Zone- 4 N/A N/A 5.Directional or Inclination Survey: Yes 0(atteched) 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: Blossom 1: ROP-DGR-ALD-ALD Image and Dip Plot MD,ROP-DGR-PCG-EWR-ADR-ALD-CTN 2"and 5"MD,ROP-DGR-EWR-ALD-CTN-ALD Image 2"and 5"MD, DGR-PCG EWR-ADR-ALD-CTN 2"and 5"TVD,Formation Evaluation Log 2"and 5"MD,Drilling Engineering Log 2"MD,Gas Ratio Log 2"MD ( 'BL.) Blossom 1 PB1:ROP-DGR-PCG-EWR-ADR-ALD-CTN 2"and 5"MD,DGR-PCG-EWR-ADR-ALD-CTN 2"and 5"TVD,Formation Evaluation Log 2"and 5"MD, Drilling Engineering Log 2"MD,Gas Ratio Log 2"MD 6tf4 /,./.,'F- ),, /1. -6,_._, /-St-/, 23. CASING, LINE AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 84# X-56 Surf 110' Surf 110' Cond Driven 10-3/4" 45.5# L-80 Surf 2,495' Surf 1,585' 13-1/2" L-277 bbls 11.9#/T-52 bbls 15.4# 31 bbls 7-5/8" 29.7# L-80 Surf 6,785' Surf 3,406' 9-7/8" j B`j'1 bbls 13.5#/T-52 bbls 15.3# 4-1/2" 12.6# L-80 6,563' 11,198' 3197' 7,582' 6-3/4" 175 bbls 15.3#Class G 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" 6,563' Tie Back-6563'MD/3197'TVD 1.8,345-8,365'MD/4,893'-4,912'TVD 2.8,844'-8,874'MD/5,365'-5,393'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. 3.9,440'-9,448'MD/5,923'-5,931'TVD Was hydraulic fracturing used during completion? Yes ❑ No j 4.9,900'-9,930'MD/6,356'-6,384'TVD 5. 10,324'-10,340'MD/6,757'-6,772'TVD Per 20 AAC 25.283(i)(2)attach electronic and printed information 6. 10,392'-10,408'MD/6,821'-6,836'TVD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED CIBP @ 10,485'MD 7. 10,492'-10,512'MD/6,915'-6,934'TVD(isolated w/plug) 8. 10,536'-10,561'MD/6,956'-6,980'TVD(isolated w/plug) 9. 10,580'- 10,610'MD/6,988'-7,026'TVD(isolated w/plug) 10. 10,582'- 10,612'MD/6,990'-7,028'TVD(isolated w/plug) 11. 10,971'-10,986'MD/7,368'-7,382'TVD(isolated w/plug) 2-7/8"6 SPF for all Perfs.(12 SPF for 10,582'-10,610'MD Reperf) 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): No Production N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period 0 0 0 N/A N/A Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 0 0 24-Hour Rate —► 0 0 0 N/A RBD 1 q Form 10-407 Revised 5/2015 -e.–(:;:/ G CONTINUED ON PAGE 2 RBD NOV 0 4 20 5C Submit ORIGINIAL on'y Z'!'t//6 ` Y"—`-' -•i‘ U 28.CORE DATA Conventional CID): Yes ❑ No 0 Sidewall Coreses ❑ No Q 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 E1 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 Lower Sterling 3866 1926 information, including reports,per 20 AAC 25.071. Beluga 5585 2405 BLG-20 5919 2630 BLG-49 6528 3164 BLG-50 6660 3288 BLG 90 7729 4301 Tyonek 8652 5184 T1 8702 5231 T2 8803 5327 T7 9194 5693 T10 9671 6140 T13 9868 6326 T18 10325 6757 T50 10972 7368 Formation at total depth: Tyonek 31. List of Attachments: Casing and Cement Reports, Daily Operations Reports, Days vs Depth,MW vs Depth Graph, Definitive Directional Surveys,Wellbore Schematic,As built survey plat 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: mmyers(a�hilcorp.com Printed Name: Monty Myers Title: Drilling Engineer Signature: ~` ` Phone: 777-8431 Date: //, 2 . Z o /5— INSTRUCTIONS General: This form and the required attachm ovide 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 1a: 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 1 b: 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 and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 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 ND 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 5/2015 Submit ORIGINAL Only Ninilchik Unit Well: Blossom#1 ACURRENT SCH EMAT PTD:215-015 API: 50-133-20648-00 Ililcorp Alaska,LLC CASING DETAIL 1 Size Type Wt Grade Conn. ID Top Btm r 16" Conductor 84 X-56 Weld 15.010" Surf 110' le.f1`"; 10-3/4" Surf.Csg 45.5 L-80 BTC 9.950" Surf 2,495' i 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 6,785' Ig t '� 4-1/2 " Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,563' 11,198' 3 � i TOC @ TUBING DETAIL 10_3/4 , '' - 2,000' 4.1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,563' 4 a °s' JEWELRY DETAIL i 'vill No. Depth ID OD Item 3 5 ' 1' 1`5" 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" M4. 6 2 19' 3.958" 4.500" Pup Joint 7_5/899 + r *t ,` 3 2,019' 3.813" 6.500 4-1/r Chemical Injection Mandrel a '+ . 4 6,563' 3.958" 4.500" 4-1/2"Seal Assembly Shoe @ 6,785'.4.,A1:, �,e 4 5 6,563' 4.500" 6.500" Liner Tie-Back Receptacle ~ ii 1 6 6,563' 5.000" 6.672" Liner Top Packer RA Mkr Jt i4' 7 10,485' CIBP 8,207' 1' 4«1/, PERFORATION DETAIL RA Mkr Jt w 1•«r Sands Top(MD) Btm(MD) Top(ND) Btm(ND) Date Size Status 8,780' %.9.. �- B134 8,345 8,365 4,893 4,912 9/4/15 2-7/8" Open ,,w. ` T3 8,844 8,874 5,365 5,393 9/3/15 2-7/8" Open A 18 9,440 9,448 _ 5,923 5,931 10/20/15 2-7/8" Open RA Mkr Jt • t T13 9,900 9,930 6,356 6,384 9/2/15 2-7/8" Open 9,984' ' 'ie 117 10,324 10,340 6,757 6,772 9/1/15 2-7/8" Open +' 118 10,392 10,408 6,821 6,836 _ 10/19/15 2-7/8" Open r" ____-3 T28 10,492 10,512 6,915 6,934 8/3/15 2-7/8" Isolated 128 10,536 10,561 6,956 6,980 8/2/15 2-7/8" Isolated 0,03' Jt T28 10,580 10,610 6,988 7,026 8/2/15 2-7/8" Isolated T28 10,582 10,612 6,990 7,028 8/27/15 2-7/8" Isolated T50 10,971 10,986 7,368 7,382 8/1/15 2-7/8" Isolated RAMkrJt ' A+_, 10,697 eSN5 , 8134 ----" T3 " T8 --4-='---Ii-T13 rA T17 T18 . ti c_181-) /c"(1• , 1 7 ..� - T28 T28 i 4 1* T50 A 4-1/2" 1 141kr- , • yis Shoe @ 11,198'-6-3/4"hole PBTD=10,485'MD/6,908'TVD TD=11,200'MD/7,584'ND Max Deviation:77 deg Max Dogleg:6.6 deg/100 Updated by C1D 10-26-15 111 • 131 Hilcorp Energy Company Composite Report Well Name: NINU Blossom 01 Field:Ninilchik County/State: ,AK 1(LAT/LONG): evation(RKB): 18 API#: 50-133-20648-00 Spud Date: 5/24/2015 Job Name: 1413217D Blossom#1 DRILLING Contractor AFE#: 1413217D AFE$: Activity Date Ops Summary 5/19/2015 Scope down derrick and lay down torque tube and top drive,rigged up and unstring drilling line from blocks and crown,,removed 1 brake band from draw works drum for MPI inspection,removed blocks from derrick and prepare for transport.,Remove the remaining brake band and linkage for MPI inspection,rig down and prepare catwalk for transport.;RD mud pits 1,2 and 3-mud pumps#1-top drive HPU-gen#3.Rig down water,air,electrical and hydraulic lines.;Rig down miscellaneous ground equipment(berms,containment and rig mats).;;75%Rig Down 0%Set in 0%Rigged up. 5/20/2015 Prep and lay over derrick,Peak on location at 07:00,held PJSM with rig team and Peak truckers,spot crane and remove centrifuge,ship gen sets,pump skids, HPU skid,catwalk.Lower doghouse,load;and ship exposed rig mats,ship 5"thread protectors,pallet stacks and rain-for-rent pump and filter skid to town.Ship pit modules,pick BOP stack from cellar,pick iron roughneck off floor,spot;2nd crane and pick derrick off carrier,pick drill line spool off carrier,pick carrier off sub,pick sub off pony walls,remove pony walls from mats.Load and ship mats,ship sub and carrier.Cut and;place liner material.;Blossom Pad:Set rig mats,spot sub over the hole,pick and set carrier,Two craned the derrick onto carrier set and pinned,set in water tank,pick dog house set and pinned.;Start hyd.pumps&raise derrick, set in mud pit and R/U,set in MCC module,install brake bands on drawworks,spool on 3/8 line on draw works drum&string up blocks.;;95%R/D and moved-70% Set in-40%R/U. 5/21/2015 Set both pump skids and run electric cords for same,mechanic inspecting right angle drive and chains on drawworks.RD and transport 4 trailers from KGF to Blossom Pad.Welder replacing hatch hinges;in pits,received casing spools,spot and RU catwalk,lay over beaver slide,set centrifuge,set iron roughneck.Install brake linkage(MPI inspected),spot office trailers,spot water tank and cement;silo's,received 3 loads 4 1/2"DP,receive connex's.Handy Berm on location installing rig containment,spot service shacks,string drill line through new blocks,cont to receive rig mats,seals.;lnstall torque tube,Total Safety cont.install and calibrate gas detection equipment,spool on drilling line onto drawworks,Scope up derrick,Installed all rig electrical lines,;installed water lines for mud pumps 1&2, pick up top drive and make up service loop and Kelly hose,picked and spotted gas buster,function test top drive,installed bails and elevators.;R/U rig tongs, change liners in mud pumps.;;100%Moved to Blossom#1-100%Set In-85%R/U 5/22/2015 Torque IBOP in topdrive quill shaft,torque saver sub and install clamps.Adjust service loop and hydraulic lines.Stab spacer spool,21 1/4"diverter"T"and Saxon's 21 1/4"annular.;Torque same.Install 16"knife valve.Install Hilcorp 16"vent line to offside of catwalk with anchor blocks.Install flow riser.Calibrated topdrive torque and installed rotary sensor.;Received 64 joints 10 3/4"surface casing(includes 3 shoe track joints),offload 4 1/2"DP from Peak trailers and stage in pipe bunks. String and install power cable from rig to water well.;Lay out and MU 2"hardline from water well to rig.Cont to dress rig pump to 5 1/2"liners.Inspect and clean all suction lines and pump manifolds.Took on 4400 gallons rig fuel.;MWD Rep on location and prepped comm's,shack and tools for PU.DD on location inspected drilling tools and OD/ID same.Peak built access from pad entrance road to hay field at request of land owner.;Finish rigging up diverter lines,Change out saver sub on the top drive and adjust torque,install shaker screens,rig up centrifuge and function test,test hoppers 1&2,function test mud pumps.;Change out wash pipe on the top drive,clean water tank,change oil on gear box on the top drive,change out oil on swivel on top drive,change oil in the right angle gear box.;;Hauled 0 bbls cuttings to G&I Total cuttings hauled=0 bbls Hauled 50 bbls Class II fluid to G&I Total Class II fluid hauled=50 bbls 5/23/2015 Take on well water in pits 1 through 6 and start mixing gel.Cont to troubleshoot topdrive hydraulic issue.Function test diverter system,load top of bag with water and allow to sit 30 minutes,;no water loss.Corrected topdrive hydraulic issue,change oil in HPU and circ fluid through filters for cleaning/flushing of system.Cont to clean and organize location.Receive 656 sx lead cement in;silo's,received one load DP and HWDP,3 loads mud products from Bartolowits Pad,received Peak dragon boxes and rolloff truck.Total Safety on location for diverter function test.;AOGCC Rep Lou Grimaldi on location for diverter function test at 15:00 hrs and .l v signed in at Pushers shack.Remove thread protectors from 10 3/4"casing in prep for drifting.;Remove 16"x 6'tail pipe from vent line and install 45 degree elbow at Y t ff request of AOGCC Rep Lou Grimaldi,to clear any flow over top of gravel bank.Function test diverter system with no failures.;Function tested diverter with 4 1/2" joint DP and 950 psi on annular.Knife valve open time=17 seconds,annular closure time=43 seconds.Placed water on top of closed bag with no leakoff.;lnstalled 14"ID wear ring,set geronimo anchor block and line,replace psi transducer in mezzanine,function test ESD's,test pump alarms. ACCEPT RIG at 18:00 hrs on 5-23-15.;F/U and rack back 30 stands 4 1/2"DP in derrick.and 8 stands of HWDP.;Rig Service(adjust torque tube rail).;Pre-job safety meeting/spud meeting.;P/U up Dir.Tools without MWD(bit-motor-dm collar-tm collar-bottle neck xo)tagged bottom 110'.;Fill hole with water and check for leaks(no leaks).;Displace water out with 180 vis spud mud and begin rotary drilling f/110'to 240'pumping 487 gpm;30 rpm; 1042 psi;3k tq.;POH to pick up the remainder of the BHA.;;Hauled 0 bbls cuttings to G&I Total cuttings hauled=0 bbls Hauled 0 bbls Class II fluid to G&l Total Class II fluid hauled=50 bbls • • 5/24/2015 MU 2 jnts 8"NM flex DC's,XO and 2 jnts 6 3/4"NM flex DC's and 2 jnts HVVDP.;Eased toward bottom and attempted to obtain survey at 175'.Had issues with detection,worked with parameters and obtained survey.Cont to bottom at 240'.;Resumed drilling 13 1/2"surface hole from 240'to 794',also PU drilling jars and XO's.Sliding:wob 10K,477 gpm-1055 psi,163 psi diff,125 to 165 ft/hr ROP.Rotating:wob 16K,489 gpm-1396 psi,;40 rpm-5600 ft/11)s on bott torque,147 to 182 / ft/hr ROP.MW 9.0 ppg/130 to 200 vis.Drifted and strapped 10 3/4"casing,Cameron Rep installed hanger on landing joint.;Cont.drilling 131/2"hole from 794'to 1226'Sliding:wob 15K,550 gpm-1695 psi,163 psi diff,125 to 140 ft/hr ROP.Rotating:wob 19/20K,550 gpm-1795 psi 45 rpm,;7500 tq on bottom,170 fUhr ROP. MW 9.2 ppg/150 to 210 vis.;Cleanup Cycle:(Beginning)P/U 48K S/O 42k Rot 42k Torque off bottom 5800 pumping©480 gpm 1275psi.;(Ending)P/U 48K S/0 42k Rot 42k Torque off bottom 5600 pumping @ 480 gpm 1185 psi.A high density sweep was pumped during the cleanup cyde.;Sweep brought back 10%more on the shakers and came back at calculated strokes.;Orient motor high side of the hole;Stop pumping and monitor well;TOH f/1226'to 789'where it pulled tight,(20k over)attempt to work through tight spot(no go).;Screwed into the top drive and turn pipe 180 deg.below the tight spot,pulled up through with no overpull;slacked off to see if anything was there(no obstruction observed);continued POOH to 240'with no problems.;Service Rig:Top Drive and Drawworks.;TIH f/240'to 1226'(no problems no fill).;Cont.drilling 13 1/2"hole from 1226'to 1412'Sliding:wob 5/15K,550 gpm-1750psi,60 psi diff,60 to 150 fUhr ROP.Rotating:wob 15/20K,550 gpm-1805 psi 40 rpm;9000 tq on bottom,170/300 ft/hr ROP.MW 9.2 ppg/150 to 210 vis.(keeping ROP below 200 fph due to hole cleaning);;Hauled 450 bbls cuttings to G&I Total cuttings hauled=450 bbls Hauled 90 bbls Class II fluid to G&I Total Class II fluid hauled=140 bbls Distance to the plan 32.75 high.20'Right TRT=4.4 TST=4.4 5/25/2015 Cont drilling 13 1/2"surface hole from 1412'to 2050',Sliding:wob 25K,551 gpm-1835 psi,120 to 200 psi diff,37 to 150 ft/hr ROP.Rotating:wob 17K,550 gpm- 1891 psi,40 rpm-9300 ft/lbs on bottom;torque,190 ft/hr ROP.MW 9.2 ppg/vis 160.BGG 18 units,connection gas 80 to 100 units.BHA is building in rotation,so we are having to slide down at times.Pumped a low vis followed with a;hi-weight sweep(40 bbls total)at 1971'with no increase in cuttings observed at surface.;Cont. drilling 13 1/2"surface hole from 2050'to(TD)2506' Sliding:wob 25K,550 gpm-1985 psi,128 to 175 psi diff,60 to 150 ft/hr ROP.Rotating:wob 18K,550 gpm- 2130 psi,60rpm-9100 ft/lbs on;bottom torque,150 ft/hr ROP.MW 9.3 ppg/vis 200.BGG 28 units,connection gas 70 to 130 units.;Cleanup Cycle: (Beginning)P/U 44K S/0 28k Rot 38k Torque off bottom 6000 pumping @ 552 gpm 1945psi. (Ending)P/U 48K S/0 36k Rot 42k Torque off bottom 5400 pumping @ 552 gpm 1885psi.;Orient motor high side;pulled tight @2,459',(25k over)attempt to work through tight spot(no go)dropped down below tight spot and engaged pumps easing rate up to 450 gpm 1505 psi.;and pulled up through tight spot with pumps on with no rotation(no over pull)decision was made to continue to pumping out to 1200'and perform a cleanup cycle.;;Hauled 720 bbls cuttings to G&I Total cuttings hauled=1170 bbls Hauled 90 bbls Class II fluid to G&I Total Class II fluid hauled=230 bbls Distance to the plan 8.67'Low 7.94'Right TRT=6.7 TST=5.5 5/26/2015 Cont to circ hole clean at 1235'.428 gpm-1100 psi,50 rpm-5900 ft/lbs off bolt torque.Initial pump rate of 550 gpm we were losing fluid.Reduced pump rate and losses diminished.Total loss 60 bbls.;VMth hole clean,cont pull up hole on elevators from 1235'to 973'and encountered tight hole(30K overpull).MU topdrive and cont pump OOH from 973'to 775',380 gpm-930 psi.At 775'we lost retums.;RIH 2 stands from 775'to 910'getting displacement.Idle one pump to establish returns(OK)then start second pump.Ease pump rate up to 400 gpm-950 psi,43%flow.Rotate at 20 rpm-3300 ft/lbs;and cont to ease up hole to 853'with no detectable losses.Rack stand back and cont same parameters,400 gpm-971 psi,20 rpm,47%flow.Pulled to 800'and had an increase in pump psi as well ? ` as;reduction in flow.Drop down 4'and regained original parameters.Ease up hole in 6"increments and allow hole to clean up.Rack second stand back.MU topdrive and cont ease up the hole at 400 gpm-;968 psi,20 rpm-3000 to 4000 ft/lbs torque,46%flow.Unable to pass 775'Orient Mtr HS do pump.;Pooh on elevators and work tight hole f/770'U+-655'continue pooh U+-175'.;Monitor well&service rig TDS,DWK,Crown and clean MP screens.;Rih f/175'U 2506'wash C' last std to btm w/no fill w/2.4 bbls over calc.;Pump vis marker sweep w/nut plug and circ hole clean(marker channeled bad came back+-70 bbls eariy)pump dry job.;Pooh on elevators to BHA;no significant over pull on during trip out of the hole.;BHA-rack back two stands 6 3/4 flex collar in derrick;lay down the rest of the BHA.;Rig down drilling bails and rig up casing bails;Weatherford power tong and elevators.;PJSM;P/U float equipment&test(good);Run 10 3/4 surface casing i 1154'. 5/27/2015 Cont running 10 3/4 casing and installing bow spring centralizers as per plan.P/up&m/up landing jt w/hanger&land same w/shoe @ 2495'w/no fill and 12 bbls over displacement Up/dn wt 110/34k.;Brk circ&stage rate up to 6 bpm at 125 psi and reciprocate pipe keeping+/-2'from land out&circ btm up;"'verified plugs were loaded properly'''.;PJSM remove circ swedge&install cmt head.;Continue circ&condition mud for cmt job&build mud push.;PJSM,SLB pump 20 bbls water&flush circ lines to pits;test lines 660/3414 psi(good).Rig pumped 45 bbls of mud push @ 10.0 ppg.;Launch btm plug(ok)SLB mixed&Dump 277 bbls =per (620sx)of 11.9 ppg lead cement followed by 52 bbls(237sx)tail cement(dt 15.4 ppg.;Launch top plug&pump 20 bbls fresh water&$LB displaced w/211 bbls of G e4 9.29.2 PPG mud&bumped plug 1 bbl early from calc.pressure up t/1200 psi for 5 minutes.;Bled off 1 bbl(floats holding).Lost 83 bbls during job had returns t^r• throughout job but tapering off slowed pump rate U 2.8 bpm.Got back 31 bbls of cmt.returns Cdt 11.7 ppg.;Pipe was reciprocated throughout pumping of lead cmt then landed hanger w/34k w/shoe @ 2495'CIP @ 17:45 hrs.;Flush lines from rig to cement truck;rig down cement lines and head.;lnstall pack-off;run in locked down and pressure test 300/5000(good).;N/D diverter,flow line and Accumlator lines.- Install wellhead-N/U BOP's,choke&kill lines,bell nipple,catch-can and flow line;;Hauled 0 bbls cuttings to G&I Total cuttings hauled=1440 bbls Hauled 578 bbls Class II fluid to G&I Total Class II fluid hauled=808bbls Hauled 52 bbls Cement to G&I Cumulative=52 bbls. 5/28/2015 Continue Nip/un ROPF and as¢nciated erwipment Clean pits.Bring into pits stored 6%KCL/PHPA&treat same and build volume.Function test Bope(ok)attempt to obtain shell test had leak on door seal.;Re-pack&re-shell test good low.Failed high test @ 2'spacer spool.Tighten and retest failed high again.Split and lift stack to chk ring&grove(spool washed)remove same&source replacement.;Continue w/mud management chg belt on MP&repair on TDS&install drilling bails. Rack&strap dp,housekeeping.;Spool on location install same and reinstall flow box flow line and associated equipment.;Perform shell test.Leak in choke house (pressure sensor)and leak on the top flange of spacer spool installed in the BOP's,checked flange for tightness(loose).Retighten and retest(Good Test).;Service travelling block.;AOGCC Rep.will be on location to witness the initial BOP test @ 6AM due to other obligation.It was decided to pick up 4 1/2"drill pipe and rack back in the derrick.;Rig up and test BOP's 250/4000.AOGCC Rep.Jeff Jones will witness the test.;;Hauled 0 bbls cuttings to G&I Total cuttings hauled=1440 bbls Hauled 540 bbls Class II fluid to G&I Total Class II fluid hauled=1348bbls Hauled 52 bbls Cement to G&I Cumulative=52 bbls. • • 5/29/2015 Continue testina BOP's 250/4000 psi.AOGCC Rep.Jeff Jones witness the test.Had failure of CMV#4.Rebuilt same(seal washed)also HCR failed continue w/ f 5� test while replacement HCR in route from;Saxon Yard,safety valve failed,make service brk remove from floor for rebuild.Tested back up safety valve(ok),dart 't G valve failed.Function same and retest(ok)finish testing bope.;Chg out Choke HCR&rebuild safety valve and test same and flanged connections brks,Finish L(� building 6%KCUPHPA mud system.;Pull test plug&install 10"ID wear ring.;Close blinds and test csg U 2700 psi w 5.3 bbls for 30 min on chart w/23 psi loss l� (good).;Align valves and prep floor to p/up dp.;Run in 3 stands of HWDP out of the derrick;pick up 70 jnts.of 4 1/2 drill pipe(drift every jnt.)wash down and tag cement @ 2,390'pumping @ 135 gpm,185 psi.(Set 10k on firm cement).;Cleanup Cycle: (Beginning)15 rpm Rot wt.35k Torque off bottom 2294 pumping @ 190 gpm 207psi.(Ending)15 rpm Rot wt.34k Torque off bottom 2056 pumping @ 190 gpm 101 psi(No sweeps pumped).;Slip and cut off 78'of drilling line.;Pump 15 bbl slug,POOH and rack back 35 stnd.4 1/2 drill pipe&3 stands of HWDP.;P/U BHA.;;Hauled 0 bbls cuttings to G&I Total cuttings hauled=1440 bbls Hauled 360 bbls Class II fluid to G&I Total Class II fluid hauled=1708bbls Hauled 52 bblsCement to G&l Cumulative=52 bbls. 5/30/2015 Continue picking up BHA#2,upload tools,surface test ok install nukes,install corrosion ring in top flex collar.;P/up rabbit and strap 4-1/2"16.6#S-135 dp f/430'V 2298'.;Tag @ 2322'kelly up&brk circ ream and c/out cmt stringer,plugs,drip float collar©+-2409'drill solid firm cmt U shoe @+-2491'fell out©2496'.;Clean f cr out rat hole w/no weight U 2506'Dig new hole U 2526'w/5k wob,20 rpm,1500 psi w/300 psi diff @ 450 gpm w/6k tq.;Chg over U 9.2 ppg 6%KCL PHPH mud system. Pull back into shoe.;R/up and performed FIT U 12.1+ppg w/242 psi applied pressure w/9.2 ppq MW Cd)1592'tvd and monitor 5 min bleed off 1-227,2- n 223,3-220,4-217&5 min 215 psi. R/dn test equipment.;Drlg.9 7/8"Intermediate Section: F/2526'to 2775',Sliding:wob 6K,498 gpm-1345 psi,50/100psi diff, V"`1 1 125/165 ft/hr ROP.Rotating:wob 10K,497gpm-psi 1380.;60 rpm-on bottom torque 4950 ft/lbs,120/250 ft/hr ROP.MW 9.3 ppg with a 53 vis(ECD 9.53).;Circ. hole clean. Short trip to the shoe to add in HWDP,P/U 49k S/0 20k Rot 32 Top Drive 12k,with slack off weight being so low it made it difficult to slide.;Trip to the shoe F/2775'-T/2351'(no problems).Pick up 12 jnts of HWDP(Push Pipe)to assist with weight on bit.;TIH with HWDP from 2,351'to 2,720'(no problems in open hole).;Continue Dig.9 7/8"Intermediate Section: F/2775'to 2903',Sliding:wob 6K,498 gpm-1445 psi,50/150psi diff,25/200 ft/hr ROP.Rotating:wob 10K, 497gpm-psi 1498.;60 rpm-on bottom torque 8850 ft/lbs,120/250 ft/hr ROP.MW 9.25 ppg with a 71 vis.(ECD 9.51).;Total cuttings hauled=1440 bbls Hauled 540 bbls Class II fluid to G&I Total Class II fluid hauled=2248bbls Hauled 52 bbls Cement to G&I Cumulative=52 bbls.;Distance to the plan 22.09 Low 11.67'Right TRT=1.45 TST=1.79. 5/31/2015 Continue Dig,9 7/8"lnt rmediate Sertinn F/2903'to 3587',Sliding:wob 7K,500 gpm-1500 psi,275psi diff,Rotating:wob 7K,500 gpm-psi 1600.;80 rpm-on bottom torque 13k ft/lbs,120/250 ft/hr ROP.MW 9.3 ppg with a 71 vis.(ECD 9.62)Pump 25 bbl high vis sweep©3377'w/no noticeable increases in cuttings;ceased MAD passing slide sections due to losing angle,Slides are spotty,worked on same getting them dn to 15-20'a std to keep our angle.;Circ btm/up rotate and reciprocate @ 80 rpm 500 gpm @ 1600 psi&flow chk(ok).;Pooh stort trip to shoe on elevators work thru tight spot+-20k over @ 3522',2952'.;Monitor well rig service.;TIH F/2,342'T/2,719';Drill string started taking weight©2,420'(20k)continued running in the hole until the BHA was 200'out of the casing,circ. bottoms up.;Pumped 20 bbl Hi-Vis sweep at 2,719'500 gpms 1650 psi.25 rpms(ECD 9.67)with 40%increase in cuttings to surface(Ending ECD 9.51).;TIH F/2,719'to 3,587'no significant problems @ 2,952'or 3,522'the work that was done coming out of the hole fixed the problem.;Drlg.9 7/8"Intermediate Section: F/3,587'to 4,279',Sliding:wob 7K,500 gpm-1750 psi,150/200psi diff,Rotating:wob 7/10K,500 gpm-psi 1800.;60/80 rpm-on bottom torque 7k ft/lbs,120/170 (limted)ft/hr ROP.MW 9.3 ppg with a 71 vis.(Beginning ECD 9.76 End 9.65)Pump 20 bbl high vis sweep©3,745'w/increases in cuttings of 60%;sweep#3 was pumped @4,039'w/increases in cuttings of 25%(beginning ECD 9.8-ending 9.69).;Haul 360bb1.cuttings to KGF G&I Total cuttings hauled=1800 bbls Hauled 540 bbls Class II fluid to G&l Total Class II fluid hauled=2248bbls Hauled 52 bblsCement to G&I Cumulative=52 bbls.;Distance to the plan 11.30 low 1.60'left TRT=7.13 TST=3.85 �( Or' -n"00 6/1/2015 Continue Orig.9 7/8"Intermediate Section: F/4265'U 4513',wob 7K,rpm 80,diff 275 psi,1750 psi©530 gpm w/slides to maintain direction.;Had near miss while drill dn stand.An improperly secured ODS tugger line flopping in the wind caught safety clamp on kelly hose and once it pull tight bent"S"pipe extension.;When noticed P/up off btm&inspected all.Saxon deemed ok for use until replacement on Iocation.;Loaded tandem 25 bbl 9.1 ppg 45 vis low vis sweep followed by a 25 bbl 9.3+ppg high vis sweep in pipe while drilling.;Circ sweeps OOH w/+-20%increase in cuttings.;Short trip Pooh f/4513'U 3200'on elevators and worked thru tight spot up 35k over @ 4021',3998',3622',Unable to work by&backreamed f/4030'-4007'and 3727'-3665'.;Pull w/no problems at 3585'(previously wiped hole section).;Pump 25 bbl high vis sweep around w/+-30%increase in cuttings.;Monitor well w/no noticeable seepage losses&service rig.;Rih w/no significant problems U 4513'and no fill also moved HWDP(push pipe)back up hole.;Resume drilling f/4513'U 4641'and slides as needed for direction.New"S"pipe extension on location pull and set back one std.;Rig on dn time.Chg out"S"pipe extension&test V 3000 psi(ok)rih one std.;Continue Dig.9 7/8"Intermediate Section: F/4641'U 4886',wob 3/7K,rpm 70/80,diff 275 psi,2040 psi @ 530 gpm w/slides to maintain direction ECD 9.89 BG gas 7.;Circ high density sweeps around w/+-60%increase.;Wiped back to 4504'no problem.;Circ.bottoms up(No sweep)w/+-10%increase in cuttings.;Monitor well(no flow no losses)RIH with no problems.;Continue Dig.9 7/8"Intermediate Section: F4886'-T/5126'wob 7/10K,rpm 70/80,diff 170 psi,2040 psi @ 530 gpm w/slides to maintain direction ECD 9.82 BG gas 125.;;Haul 450bb1.cuttings to KGF G&I Total cuttings hauled=2255 bbls Hauled 5 bbls Class II fluid to G&I Total Class II fluid hauled=2253bbls Hauled 52 bblsCement to G&I Cumulative=52 bbls.;Distance to the plan 1.66 high 1.24'left TRT=6.64 TST=1.96 6/2/2015 Continue Drip.9 7/8"Intermediate Section: F/5126'V 5261',up/dn/rot 70/34/46 wob 7K,rpm 80,tq 11.5k diff 300 psi,1950 psi @ 530 gpm w/slides to maintain direction.;Circ btm up and pump around tandem sweeps,20 bbl low vis sweep©9.1 ppg @ 40 vis followed by a 20 bbl weighted high vis sweep @ 11.3 ppg and +300 vis;while rotating 80 rpm and reciprocating full std and pumping at max rate 530 gpm only slowing to get weighted thru Mwd©(450 gpm). W/+-10% increase w/low&+-35%increase w/weighted high.;Short trip Pooh f/5261'U4148'on elevators and worked thru tight spots,up 30k over @ 5138',4960',4930'& 4728'(coal).;Pump 20 bbl high vis sweep around w/+-15%increase in cuttings.;Monitor well w/>1 bbls seepage loss&service rig.;RIH w/no significant problems f/4148'U 5261'w/no fill also moved HWDP(push pipe)back up hole.;Resume drilling f/5261'U 5384'and slides as needed for direction.up/dn/rot 70/34/49.wob 7k,@ 80 rpm w/tq @ 11k w/530 gpm and 1900 psi diff @ 275psi. Enter top of Beluga formation @ 5285'.;Continue drilling f/5384'U 5677',25-30'slides every std to maintain 5 deg DLS drop per 100'.up/dn/rot 80/30/52,wob 4-6k, 80 rpm,tq 10k pumping 528 gpm,2100 psi,diff 150 psi.;MW 9.5 ppg,vis 57,ECD 9.85 ppg.BGG 60u.No Iosses.;Continue drilling f/5677'to 5892'w/25-30'slides every std.up/dn/rot 90/40/58.wob 4-7k.80 rpm,tq 10k pumping 528 gpm,2150 psi.diff 160 psi.MW 9.5 ppg,vis 62.ECD 9.96 ppg.;No losses.BGG 19u.Pump 20 bbl hi vis sweep with walnut©5739'while rotating 80 rpm.sweep back on time w/25%increase in cuttings.;7.85 slide hrs,4.03 rotate hrs.Average ROP 45 fph. Currently 1.41'below the line and 0.54'left of the Iine.;;Hauled 540 bbl.cuttings to KGF G&I Total cuttings hauled=2790 bbls Hauled 40 bbls Class II fluid to G&I,Total Class II fluid hauled=2293 bbls Cement to G&I,Cumulative=52 bbls. • • 6/3/2015 Continue Drlg.9 7/8"Intermediate Section: f/5879't/5999',up/dn/rot 100/45/59 wob 7-10K,rpm 80,tq 11.5-13k diff 300 psi,2150 psi @ 530 gpm w/slides to maintain direction.;Having some problems w/slides.Decide to pull short trip and move HWDP(Push pipe)back up hole and check hole for cuttings in an attempt to help slide problems.;Pump 20 bbl high vis sweep and circ btm up.Btm/up had 10%and sweep had 25%increase.Pump around tandem sweeps,20 bbl low vis sweep @ 8.9 ppg @ 38 vis followed by a;20 bbl weighted high vis sweep @ 11.3 ppg and+300 vis w/60-70%increase.;Check flow and noticed slight seepage loss.Pooh f/5999'94892'on elevators and worked thru tight spots,up 35k over @ 5726',5547,5463'&5313'.;Had 4 bbls over on displacement.Pump 20 bbl high vis sweep around w/+-15%increase in cuttings @ btm up and 50%surface to surface.;Monitor well w/no seepage loss&service rig.;RIH w/no significant problems f/4892'1/5999'took weight&had to take another run at it @ 5354'had no fill also moved HWDP(push pipe)back up hole.;Resume drilling f/5999'U 6065',Attempting slides maintain 5 deg DLS drop per 100'.Still difficult sliding,only making 3-5 fph.pu/so/rot 90/40/48.wob 3-5k,528 gpm,2170 psi.Diff 151 psi.;Continue drilling f/6065'to 6095',note:add NXS lube and maintain @ 1%in system,motor stall @ 6095',attempt to pull free pulling 160k,cannot rotate,w/ pump off work free pulling 175k,;75k overpull,setting off jars.Ream stand,Continue drilling from 6095'to 6166'with lube in system slides improved from 3-5 fph to 40-60 fph w/no overpulls off bttm.;pu/so/rot 95/43/58.80 rpm,tq 10k,wob 4-5k,528 gpm,2150 psi.diff 155.MW 9.4 ppg,ECD 9.77 ppg,no losses.Pump 20 bbl hi vis sweep @ 6128',sweep back on time with 10%increase in cuttings;Continue drilling f/6166'to 6380'w/25-30'slides ea.std to maintain 5 deg DLS per 100', pu/so/rot 92/49/62.80 rpm,tq 9k,528 gpm,2150 psi.diff 125,MW 9.4 ppg,63 vis.ECD 9.88 ppg,No losses;8.34 slide hrs,2.67 rotate hrs.Average ROP 35 fph. Currently 20.9'above the line and 3.94'right of the line.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=2880 bbls Hauled 450 bbls Class II fluid to G&I,Total Class II fluid hauled=2743 bbls Cement to G&I,Cumulative=52 bbls. 6/4/2015 Continue No,9 7/8"Intermediate Section: f/6380'U 6433',up/dn/rot 109/49/64 wob 2-5k,rpm 80,tq 11.5k diff 300 psi,2120 psi @ 530 gpm.;Pump 20 bbl high vis sweep had 10%increase and 32 bbls early.Continue circ STS had increase of 20%.;Check flow and noticed slight seepage loss.Pooh ft 6433't/5999'on elevators w/no issues.Had 1/2 bbls over on displacement.;Pump around tandem sweeps,20 bbl low vis sweep @ 9.0 ppg @ 36 vis followed by a 20 bbl weighted high vis �71 sweep @ 11.3 ppg and+300 vis w/btm/up 20%increase.;Surface to surface 50%increase also came back+-32 bbls early also.;Service rig.;Monitor well w/slight �J seepage loss Rih f/5999'9 6433'w/no fill.;Rotary drill and establish rotary trend f/6433'1/TD of hole section @ 6795'also pumped 20 bbl high vis sweep around while drilling @ 6633'also back+-32 bbls early @+-35%increase.;PU/SO/ROT 109/64/49 3k on bit @ 80 RPM @ 12900 TQ 95 DIFF @ 525 GPM and 2320 psi =.3 drop per 100'.;Pump 20 bbl high vis sweep had 10%increase and 25 bbls early.Continue circ STS had increase of 10%.;POH on elevators f/6795'to 6681', flowcheck well,note:slight seepage,turn elevators,continue POH from 6681'to 5688',30k overpulls @ 6474',5932',5859',5835',5800',5766',5708',5696';and tAi 5671',working thru tight spots easily.Note:L/D jt#183 on stand#12 due to pitting on tool face,replace with new jt of DP.;M/U topdrive,pump tandem 20 bbl Lo Vis 131g, sweep followed by 20 bbl Hi Vis 11.5 ppg 300 vis weighted sweep,pump 450 gpm until sweep out of pipe. Increase pump to 525 gpm,rotate 90 rpm,;reciprocate pipe,Lo vis sweep back 25 bbls early w/100%increase in cuttings,Hi Vis sweep,hole unloaded with cuttings,200%increase,circulate hole clean.Flowcheck well, static.;Continue POH on elevators f/5688'to 4194'w/30k overpulls @ 5538',5458',4700',4667'and 4630'working thru easily.;M/U topdrive,pump 2nd tandem 20 bbl Lo Vis sweep followed by 20 bbl Hi Vis 11.5 ppg 300 vis weighted sweep,pump 450 gpm until sweep out of pipe.increase pump to 525 gpm,rotate 90 rpm.;Lo • Vis sweep back 11 bbls early with 10%increase,Hi Vis sweep @ 10%increase in cuttings.Flowcheck well w/slight seepage.;POH on elevators f/4194'into 10 3/4"casing shoe @ 2488'w/30k overpull @ 4003',3966',backream f/3022'to 3010',pulling BHA slow into shoe seen 5k overpull at stabilizers.;17.2 bbls over calculated displacement on trip to shoe.;RIH to 2529'out of shoe,m/u topdrive,circulate BU w/no increase in cuttings.;POH on elevators f/2529'to BHA,rack - I1VVDP,jars and flex collars in derrick.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=2970 bbls Hauled 360 bbls Class II fluid to G&I,Total Class II fluid hauled=3103 bbls Cement to G&I,Cumulative=52 bbls. • 6/5/2015 Stand back flex collars,PJSM for source,pull source.Download data.Pull up chk bit&mtr(ok)while monitoring well static loss rate @ 1.6 bph loss. Bit grade=1,1,CT,G,X,I,Wr,BHA.;RIH w/bha,upload data,pulse test and load source.;Rih f/430'U shoe @ 2472'fill pipe w/1/2 bbl over cal displacement.;Cut& slip 64'drlg line,reset and test crown-o-matic.;RIOH on elevators f/2472'U 6768',M/U topdrive,break circ,tag bttm @ 6795'w/no fill.Had few spots gravity took over and had to p/up to get run at it.;(in 75deg hole section block weight @ 15k dn weight 21k)one hard set dn @ 4678'and unable to pass,kelly up pump and use all of TDS and block weight to work thru.;Pump 20 bbl Hi Vis sweep around 525 gpm,rotate 80 rpm,reciprocate pipe,half way thru BU observed 50%increase in cuttings.Sweep back on time with 25%increase in cuttings.Circulate hole clean.;Pump survey.Pumps off pu/so 150/38.Mad pass log 300 fph f/6795'to 6136' pumping 530 gpm,2100 psi.80 rpm.MW 9.45 ppg,vis 63.ECD 9.92 ppg.Seepage continues @ 1.5 bph.;Pump survey every std.Record P/U,S/O wt w/pumps off every 5 stds.;Mad pass log 300 fph f/6136'to 5465'pumping 530 gpm,2080 psi.80 rpm.MW 9.5 ppg,vis 64.ECD 9.8 ppg.Seepage continues @ 1.5 bph.;Pump 20 bbl Hi Vis sweep @ 6000'while logging,sweep back on time w/10%increase in cuttings.Pump tandem 20 bbl Lo Vis,20 bbl Hi Vis 11.5 ppg 300 vis sweep @ 5500'.;Losses to the well in last 24 hrs=38 bbls 9.5 ppg drilling mud.;Hauled 0 bbl.cuttings to KGF G&I Total cuttings hauled=2970 bbls Hauled 180 bbls Class II fluid to G&I,Total Class II fluid hauled=3283 bbls Cement to G&I,Cumulative=52 bbls. 6/6/2015 Continue to mad pass 9 7/8"intermediate hole section f/5465'194670',@ 300 fph @ 528 gpm,2080 psi,80 rpm,9000 TQ pump survey every std.Record P/U, S/O wt w/pumps off every 5 stds.;Circ tandem sweep while logging f/5500'. On time w/25%increase.;Continue to mad pass 9 7/8"intermediate hole section f/ 4670'to 3770',@ 300 fph @ 528 gpm,2080 psi,80 rpm,9000 TQ pump survey every std.Record P/U,S/O wt w/pumps off every 5 stds.;Continue to mad pass 9 7/8"intermediate hole section f/3770'to 2963',@ 300 fph @ 527 gpm,1740 psi,80 rpm,9000 TQ.pump survey every std.Record P/U,S/O wt w/pumps off every 5 stds;MW 9.4 ppg,vis 65,ECD 9.71 ppg.No losses.Circ normal 20 bbl high vis sweep while logging f/3500' On time w/10%increase.;Total Safety on location @ 20:30,Replace H2S sensors on floor and cellar due to moisture,calibrate and bump test gas alarms.;Continue to mad pass 9 7/8"intermediate hole section f/2963' to 2600',@ 300 fph @ 527 gpm,1720 psi,80 rpm,8000 TQ.pump survey every std.Record P/U,S/O wt w/pumps off every 5 stds.;Circ tandem sweep @ 2600', 526 gpm,1600 psi,rotate 80 rpm on time w/20%increase.;POH from 2600'to 2466'inside 10 3/4"casing.Note 3k overpull with bit going in shoe @ 2495'. Flowcheck well for 5 min,static.POH f/2466'to BHA.;Rack HWDP in derrick,L/D jars and flex collars.;;Losses to the well in last 24 hrs=0 bbls.Total 38 bbls 9.5 ppg drilling mud.;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3060 bbls Hauled 360 bbls Class II fluid to G&I,Total Class II fluid hauled=3634 bbls Cement to G&I,Cumulative=52 bbls. 6/7/2015 UD BHA#3.Pull source,download data(Passed field QC).;Pulled wear ring and flush profile and stack,static loss rate 1.3 bph loss rate.;Closed blinds rams and j� chg upper rams f/VBR's f/7-5/8"rams and function test(ok).;P/up m/up 7-5/8"test jt and set test plug and test 7-5/8"Rams and annular t/250L&4000H on chart 5/10 each(ok). R/dn test equipment.;Continue r/up csg handling equipment and dummy run csg hanger(ok).;PJSM,p/up 7-5/8"29.70#L-80 BTC csg float track visually inspect same(ok)and baker lock first 4 jts chk floats(ok)and install centralizers as per procedure.;PJSM w/oncoming crew.Continue P/up run 7-5/8" 6-5,Y 29.70#L-80 BTC csg f/126'to 804',install centralizers as per procedure,fill on the fly and every 5 jts.Average M/U TQ 7800#.;PJSM for volant tool w/weatherford rep and crew,R/U volant running tool,demonstrate tool operation and familiarize rig crew.;Gontinue P/up run 7-5/8"29.70#L-80 BTC csp f/804'to 2474'just above rr- shoe,install centralizers as per procedure,fill on the fly and every 5 jts.1 bbl under calculated displacement to shoe.;Pump a full circulation,389 gpm,245 psi. Flowcheck well,static,Pumps off up/dn wl 56/40.;Continue P/up run 7-5/8"29.70#L-80 BTC csg f/2474'to 6760'(168 jts total)with no issues,install centralizers as per procedure(41 total to 3172')fill on the fly and every 5 jts.;18.4 bbls under calculated displacement TIH with casing.;M/U hanger and landing jt per Cameron rep, stab Volant tool,break circulation pumping 2 bpm 200 psi.Land hanger on depth @ 6785'(20.2'to land).;P/U out of hanger profile,up/dn wt 112/48,stage pump up to 276 gpm,322 psi.Circ and condition mud for cement job with full returns,R/U cementers.;;Losses to the well in last 24 hrs=31 bbls.Total 69 bbls 9.4 ppg drilling mud.;Hauled 0 bbl.cuttings to KGF G&I Total cuttings hauled=3060 bbls Hauled 90 bbls Class II fluid to G&I,Total Class II fluid hauled=3733 bbls Cement to G&I,Cumulative=52 bbls. • • 6/8/2015 Continue circulating and conditioning mud for cmt job while reciprocating 7-5/8 intermediate csg Up/Dn 112/58k©277 gpm @ 324 psi.;Land hanger w/shoe 6785'attempt to release Volant casing running tool with no success ended up backing out Volant csg running tool and landing jt top pup as one b044 and I/dn same.M/up new pup on landing jt and p/up m/up cmt head r/up circ lines;Resume circ and cond.PJSM on cmt job.Pump flush cmt line w/15 bb6 water to �P^' pits. Pressure test cmt line t/600L and 4800H(ok). Resume circ mud.;Rig pumped 34 bbls of 11 ppg mud push,drop bttm plug,SLB mix and pumped,$?(bbls of 13.5 ppg lead cmt+52 bbls of tail cmt @ 15.3 ppg,drop upper plug.;Then displaced w/10 bbls water+3011121S mutt P_u_mped hshoelrack_(no_bump),.floats w/3/4 bbl back.CIP @ 14:58 hrs.;R/dn cmt head and lines.pull landing and run and install pack-off,RILDS.Test pack off,500 psi low f/5 min&5000 psi high for y 15 min(ok).;Closed blinds rams,C/O upper 7-5/8"rams to 2 7/8"x 5"VBR.;PJSM.R/U test equipment,set test plug,flood stack with water,using 4 1/2"test jt shell eAd test BOP to 4000 psi,good test.;Test BOPE.AOGCC rep Jim Regg waived witness on 6/7/15 @ 12:19 hrs.Test rams,annular,mud cross valves,choke man, upper/lower IBOP,Dart valve,FOSV to 250 psi low 5 min ea.;4000 psi Hi 10 min ea,charted.Perform electric and manual choke bleed test,accumulator drawdown test.No failures.Total Safety calibrated and tested gas alarms on 6/6/15,R/D test equipment.;lnstall 9"ID wear ring.R/I 4 LDS.;Service Drawworks and Topdrive.;Prep rig floor,drift,P/U and RIH with 4 1/2"Drill pipe to complete production section.(124 jts total).;;Hauled 0 bbl.cuttings to KGF G&I Total cuttings hauled=3060 bbls Hauled 90 bbls Class II fluid to G&I,Total Class II fluid hauled=3823 bbls Cement to G&I 75 bbls,Cumulative=127 bbls. 6/9/2015 Drift,P/U and RIH with 4 1/2"drill pipe to complete production section,to 3851'(124 jts total).MU topdrive and circ through pipe to clean up same.;Service rig and topdrive while C/O tong torque line and sheave.;TIH with 5 stands HWDP from derrick to 4161'.;Held safety stand down with HSE Rep Matt Hogge,Production Supervisor Pete Iverson,rig team and all service Rep's,pertaining to recent incidents at KGF not affiliated with Saxon 169.;POOH and LD excess HWDP from 4517'to 4250',then cont to POOH racking back all 4 1/2"DP in derrick.;PJSM,stage BHA components,PU 5"motor,MU Varel 6 3/4"bit jetted w/6 x 11's,MU DM collar and scribe same.RFO=214.28 degrees.MU gamma collar,ADR and ADL collars,MU CTN collar and PWD collar.;Download MWD,MU topdrive and shallow pulse test(OK),PJSM and install RA sources.M/U TM collar,2 flex collars,xo,6 jts HWDP,xo,jar,xo and 7 jts HWDP=610.13';TIH from 610'to 1100', Pipe count off,numbered incorrect.POH to 610'to verify pipe count,TIH to 1100';TIH from 1100'to 6475',fill pipe©3000',S/O string wt TIH thru tangent section f/ 3800'to 5200' at 15-20k,fill pipe every 15 stds giving additional string wt to assist w/TIH.;Install IT-spiro torq cuttings impeller on std#75 at 5262'then every 2nd std,install collar clamp,M/U,breakout,re-dope and M/U impeller connections;Fill pipe,circulate out air.R/U test equipment;;Hauled 0 bbl.cuttings to KGF G&I Total cuttings hauled=3060 bbls Hauled 90 bbls Class II fluid to G&I,Total Class II fluid hauled=3913 bbls Cement to G&I,Cumulative=127 bbls. ! !i 6/10/2015 Cont to circ air out of pipe at 6480'(220'above FC).RU test equipment/chart recorder.;Test 7 5/8"intermediate casing to 3500 psi for 30 min on chart.Had leak at rest' ��LL gland nut on wellhead.Bled off,tightened same,pressured up to 3500 psi with 59 strokes of rig pump(4 bbls).Test good.;Bled off 4 bbls and RD test equipment.;Cont to ease in hole,dwn wt 40K,from 6480'and tag hard cement at 6630'(70'above FC).;Break circ at 250 gpm-1553 psi,30 rpm=13,000,rotating: 66 up wt 98K,dwn wt 58K,rot wt 62K.With surface volume blended at 9.1 ppg commenced drilling cement and upper plug(black)down to;lower plug and FC at 6700'. ((�J Drilled shoe track down to float shoe at 6785',wob 1 to 2K,308 gpm-2024 psi.'Drilled rat hole and 20'of new formation to 6815'.VV,OB 2 to 7K,344 gpm-2356 psi, 35 rpm-13,800 to 15,600 ft/lbs on bolt torque.At 6815'we are in 80%siltstone,20%sand.;CBU 1 time at 344 gpm-2360 psi.Having serious drag issues when trying to work drill string up hole.140K up,45K down.Notified Drilling Engineer and decision made to add NXS lube at 1/2%.;Remove topdrive,MU headpin and circ hose,MU test hose to chart and circ down pipe and kill line to clear air from lines.Close upper pipe rams.Pressure up to 514 psi with.62 bbls pumped.;Pressure dropped from 514 to 500 psi over first 3 minutes,then held steady for a total of 10 minutes.9.1 ppg mud at 514 psi=12.0 ppg EMW,Bled back.50 bbl,RD test equipment and chart.;Cont drilling 6 3/4"hole from 6815'to 7005',wob 6-8k,350 gpm,2380 psi,60 rpm,15500-16500k ft/lbs on bolt torque,95 fUhr ROP,P/U 160K,S/O 35K,ROT 65K.MW 9.1 ppg/72 vis,ECD's at 11.18 ppg.;Diff 75 psi.No losses.Continue to add cuttings impellers on every 2nd stand.Add and maintain C> lube @.5%;Cont drilling 6 3/4"hole from 7005'to 7219',wob 4-7k,345 gpm,2280 psi,70 rpm,15000-16000k ft/lbs on bott torque,56 ft/hr ROP,P/U 160K,S/0 t Z 35K,ROT 65K.MW 9.1 ppg/71 vis,ECD's at 11.18 ppg;Diff 80 psi.No losses.Pump 20 bbl Hi Vis sweep @ 7180',sweep back at calculated stks with 50% increase at shaker consisting of mostly clay.Note:5 lbs metal shavings on magnets.;Mad pass slide sections.3.22 slide hrs,4.45 rotate hrs. 25.17'above the line and 3.13'right of the Iine.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3150 bbls Hauled 360 bbls Class II fluid to G&I,Total Class II fluid hauled=4273 bbls Cement to G&I,Cumulative=127 bbls. 6/11/2015 Cont directional drilling 6 3/4"production hole from 7219'to 7628' Sliding:wob 3K,343 gpm-2211 psi,36 to 124 psi diff,6 to 26 ft/hr ROP.Rotating:wob 4 to 5K, 343 gpm-2568 psi,75 rpm-14,061;ft/lbs on bott torque,98 ft/hr ROP.MW 9.3 ppg/66 vis,ECD's from 11.1 to 11.3 ppg.BGG 69 units,connection gas 100 units. Pumped lo-wt/hi-wt tandem sweep at 7468'with 20%increase in cuttings.;lncreased NXS lube from 1/2%to 1%at 7300'.Did not see much change in rotating up/dwn weights or on bottom torque,but after sweeping hole had less up wt,more dwn wt,and rotating torque reduction.;Parameters with 1/2%lube=up wt 146K, dwn wt 44K,rot wt 68K,off bott torque 16,000 ft/lbs.Parameters with 1%lube=up wt 150K,dwn wt 45K,rot wt 68K,off bott torque 16,000 ft/lbs.;BHA has been building 0.65deg/100 and walking to the right 0.6deg/100 in rotation.;Cont directional drilling 6 3/4"production hole from 7628'to 7818',343 gpm,2560 psi.5-6k wob,75 rpm,torq 13200-13800 ft/lbs.P/U 190K,S/O 44K,ROT 77K,MW 9.3 ppg,vis 62,ECD 11.33 ppg.;Pump tandem sweep,pump 20 bbl Lo vis then 27 bbl 11.1 ppg 200 vis weighted Hi vis sweep,sweep back at calc stks,Lo vis sweep 0%increase,Hi vis sweep 10%increase,mostly clay.;Mad pass slide area,Pump survey,take SPR,flowcheck well,static.;POH on elevators from 7818'to 6729'inside 7 5/8"casing.Severe drag POH,180K up wt w/30k overpulls @ 7529',7190' and 6836',working thru easily.No issues with bit or stabs entering shoe.;Flowcheck well,static.Service top drive,draworks and crown.Following top drive inspection,found middle die retainer block on top drive grabber box damaged,C/O same.;TIH from 6729'to 7754',M/U topdrive,wash last std to bttm @ 7818'with no fill.No issues on trip in,.9 bbls over calculated displacement.;Cont directional drilling 6 3/4"production hole from 7818'to 8007',343 gpm,2530 psi.4-6k wob,80 rpm,torq 13500-14000 ft/lbs.P/U 180K,S/O 43K,ROT 79K,ROP 90 fph.;MW 9.25 ppg,vis 62,ECD 11.12 ppg.Note:3 lbs metal shavings found on magnets,8 lbs total. 4.41 slide hrs,8.77 rotate hrs.11.97'above the line,9.44'right of the Iine.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3240 bbls Hauled 180 bbls Class II fluid to G&I,Total Class II fluid hauled=4435 bbls Cement to G&I,Cumulative=127 bbls. 6/12/2015 Cont to directionally drill the 6 3/4"hole section from 8007'to 8577'.Sliding:wob 3K,345 gpm-2311 psi,19 to 145 psi diff,18 to 24 ft/hr ROP.Rotating:wob 5K,344 gpm-2495 psi,;80 rpm-12,400 ft/lbs off bolt torque,70 to 80 ft/hr ROP.BGG 20 units,connection gas 200 units.MW 9.3 ppg/vis 59.ECD's at 10.91 ppg.Rotary tendency surveys is averaging 0.46°/100';build and drifting left and right in+/-0.40°/100'increments.At 8252'on bottom torque was up as high as 18,000 ft/lbs with lube down to+/-1/2%.Increased lube up to 1%,as well as pumped a 20;bbl hi-vis sweep at 8314'and on bottom torque dropped to 12,000 to 13,000 ft/lbs.Had 25%increase in cuttings with sweep to surface.;Cont to directionally drill 6 3/4"hole from 8577'to 8810',347 gpm,2650 psi.4-5k wob,75 rpm,torg13000-13500 ft/lbs,P/U 150K,S/O 48K,ROT 90K.ROP 70 fph,MW 9.25 ppg,vis 60,ECD 10.97.;Mad pass slide area,Pump tandem sweep,20 bbl Lo vis then 20 bbl 11.1 ppg 200 vis weighted,sweep back at calc stks w/10%increase in cuttings,mostly sand.;Pump survey,take SPR,flowcheck well,static.;POH on elevators from 8810'to 7708',drag @ 190k P/U wt.30k overpulls @ 7829'and 7712',working thru easily with 1 pass.1.6 bbls over calculated displacement POH.;Flowcheck well,static. RIH from 7708'to 8747',wash last std to bttm @ 8810'with no fill.2.1 bbls over calculated displacement on TIH.;Cont to directionally drill 6 3/4"hole from 8810'to 9025',345 gpm,2650 psi.4-6k wob,75 rpm,torq 15000-15500 ft/lbs,Diff 80 psi.P/U 160K,5/0 55K,ROT 92K.ROP 105 fph, MW 9.25 ppg,vis 60,;ECD 10.94 ppg.BGG 60u.No losses.Note:4 lbs metal shavings found on magnets,12 lbs total.Maintain+1%lube in system. 618u gas reported f/8892'sand.;1.81 slide hrs, 13.01 rotate hrs.8.85'below the line,12.28'right of the Iine.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3330 bbls Hauled 450 bbls Class II fluid to G&I,Total Class II fluid hauled=4903 bbls Cement to G&I,Cumulative=127 bbls. • • 6/13/2015 Cont directional drilling 6 3/4"hole from 9025'to 9182',rotating wob 5K,345 gpm-2641 psi,50 rpm-13,800 to 15,100 fUlbs on bolt torque,50 to 100 ft/hr ROP,BGG 23 to 40 units,connection gas;300 units,MW 9.3 ppg/vis 61,ECD's at 10.8 ppg.;Service rig and topdrive prior to connection.;Cont directional drilling 6 3/4"hole from 9182'to 9801',rotating wob 5K,344 gpm-2530 psi,50 rpm-14,500 fUlbs on bolt torque,50 to 100 ft/hr ROP,BGG 52 units,connection gas 500 units,MW 9.3;vis 60,ECD's at 10.8 ppg.BHA has been building+/-0.37°/100'with little to no walk left or right.Have had to do no sliding since 5AM.Pumped hi-vis sweep at 9311'with 10%increase in cuttings.;At 9801'pump tandem sweep(lo-wt/hi-vis-hi-wt)around at 342 gpm-2634 psi,sweep back 200 stks late,25%increase in cuttings to surface,mostly sand with some coal,flowcheck well,static.;POH on elevators from 9801'to 6731'inside 7 5/8"casing,drag with 210k P/U wt to previous wiper interval @ 8815'.30k overpull @ 8835,attempt to work thru,wash from 8828'to 8810'.;Continue to pull on elevators from 8810'to 8610',pump out due to swabbing from 8610'to 7420',pull on elevators from 7420'to shoe,clean w/bha thru shoe.6.5 bbls over calc.displacement on TOH.;Flowcheck well,static.Clean up rig floor from wet trip.Rebuild#1 MP pop off valve due to seals leaking,resetting and not functioning properly.;TIH from 6731'to 9666'tagging coal seam with 5k set down,M/U top drive,wash and ream from 9666'to bttm @ 9801'.No fill.7.2 bbls over calculated displacement on TIH.;Cont directional drilling 6 3/4"hole from 9801'to 9924',wob 4-6K,343 gpm,2600 psi,75 rpm,torq 16,500-17,000 ft/lbs.,ROP 50-65 fph,P/U 158K,SIO 68K,ROT 100K,1805u gas @ BU.;Holding back on ROP to+/-60'hr,in hopes we will drop inclination and walk slightly to the right in rotation.;MW 9.3 ppg,vis 53.ECD 10.79 ppg,BGG 40u. No losses.Note:5 lbs metal shavings found on magnets,17 lbs total. AST:0.88 hrs,ART:10.73 hrs At 6AM we are 9.2'low and 0.18'right of the Iine.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3420 bbls Hauled 375 bbls Class II fluid to G&I,Total Class II fluid hauled=5278 bbls Cement to G&I,Cumulative=127 bbls. 6/14/2015 Cont drilling 6 3/4"hole from 9924'to 10234'.Rotating wob 3 to 5K,345 gpm-2714 psi,80 rpm-18,200 ftAbs on bottom torque,47 ft/hr ROP.Sliding wob 7K,347 gpm-2572 psi,95 to 250 psi diff,;4 to 25 ft/hr ROP.Pumped 20 bbl hi-vis sweep at 10,000'with 25%increase in cuttings.BGG 46 units,connection gas 300 units, MW 9.3 ppg/vis 62,ECD's 10.8 to 11.7ppg.;Pumped a second hi-vis sweep at 10,205'while drilling stand down,and circulated same out at 10234'.Had 50% increase in cuttings to surface(slid most of last stand down).;Cont drilling from 10234'to 10442',wob 3-5K,345 gpm-2670 psi,80 rpm-13,700-14,200 ft/lbs on bttm torque,ROP 45-60 ft/hr,P/U 173K,S/O 90K,ROT 110K,MW 9.3 ppg,vis 63,ECD 10.77 ppg.;No losses.Note:644u @ 10240',logger reports from coal below T20.;Cont drilling from 10442'to 10636',wob 3-4K,322 gpm-2600 psi,80 rpm-14,500-15,100 ftAbs on bttm torque,ROP 32 ft/hr.P/U 180K,S/O 78K,ROT 112K, MW 9.3 ppg,vis 59,ECD 10.7 ppg.;No losses.Note:1023u gas @ 10537',logger reports from coal,1.5 lbs metal shavings found on magnets,18.5 lbs total.;4.52 slide hrs,13.19 rot hrs.5.94'above the line,1.57'right of the Iine.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3510 bbls Hauled 180 bbls Class II fluid to G&I,Total Class II fluid hauled=5458 bbls Cement to G&I,Cumulative=127 bbls. 6/15/2015 Cont directional drilling 6 3/4"production hole from 10,636'to 10,854',rotating wob 3 to 4K,345 gpm-2587 psi,75 rpm-14,800 to 15,200 ft/Ibs on bolt torque,17 to 80 ft/hr ROP,9.3 ppg/vis 69,;ECD's at 10.7 ppg,BGG 98 units,connection gas at 700 units.(824u gas from sand @ 10686',711u from coal @ 10714',818u from coal(fp 10756').;At 10,854',pumped tandem sweeps(lo-wf/hivis,hi-wt)at 326 gpm-2504 psi.Had+/-10%increase in cuttings to surface.With hole clean,took survey,slow pump rates and checked for flow(static).;POOH on elevators from 10,854'to 9670'.Up wt 200K.Pulled 30K over at 10,748'and 10,521'.Worked both spots on elevators one time.1 bbl over calculated hole fill for trip up hole.;Single in hole 10 joints 4 1/2"DP from 9741'to 10,054'.Cont TIH with stands to 10,799'. Wash last stand to bottom with no fill.Down wt 90K.;CBU one time at 345 gpm-2590 psi,hole unloaded a good amount of fine coal/sand.Had a max of 5496 units trip gas at bottoms up.;Cont drilling 6 3/4"hole from 10854'to 11044'.Sliding:wob 5K,344 gpm-2760 psi,200 psi diff,ROP 35-45 fph.75 RPM,16000-16500 ftAbs torq.Rotating:wob 5K,P/U 190K,S/O 85K,ROT 119K.;MW 9.25 ppg,vis 62,ECD 10.65 ppg,no losses.981u gas @ 11002'from coal.;Cont drilling 6 3/4"hole from 11044'to 11335',345 gpm-2650 psi,wob 5-7K,ROP 48.5 fph.70 RPM,12500-13000 ftAbs torq.P/U 188K,S/O 84K,ROT 120K.MW 9.25 ppg,vis 67,ECD 10.68 ppg,no losses.;1341u gas @ 11183'and 1163u @ 11205'from coal,.5 lbs metal shavings found on magnets.19 lbs total. 2.32 slide hrs,13.98 rot hrs.3.93'above the line,7.55'right of the Iine.;;Hauled 90 bbl.cuttings to KGF G&I Total cuttings hauled=3600 bbls Hauled 270 bbls Class II fluid to G&l,Total Class II fluid hauled=5728 bbls Cement to G&I,Cumulative=127 bbls. 6/16/2015 Cont drilling 6 3/4"hole from 11,335'to 11850',Rotating wob 5K,352 gpm-2947 psi,50 rpm-15,600 to 17,000 ftAbs on bolt torque,34 to 100 ft/hr ROP.Sliding wob 2K,338 gpm-3037 psi;40 to 112 psi diff,12 to 28 ft/hr ROP,Current MW 9.2 ppg/vis 64,BGG 100,connection gas 300 units.Changed both rig pumps over to 5" liners(one at a time)due to max psi on 5 1/2"liners.;Pumped a 20 bbl hi-vis sweep at 11,298'with 20%increase in cuttings to surface.;Pump tandem sweeps(lo- vis/hi-vis,hi-wt)around at 330 gpm-2380 psi,shoot survey and obtain slow pump rates.Flow check well(Static).;POOH for wiper trip from 11850'to 10727'on elevators.Up wt 235K,Dn 108K,Rot 148K. Worked thru tight spots @ 11049,10994,and 10902'MD. Able to work thru on elevators.2 bbl loss for trip out.;TIH F/ 10727'-T/11850'MD. Washed dn last stand,tagged up 35'fill.;CBU @ 11850'MD. 346 gpm,2920 spp,38%flow,75 rpm,14.8k tq. Hole unloaded @ btms up.;Cont drilling 6 3/4"hole from 11,850'to 12098',Rotating wob 5K,342 gpm-3045 psi,70 rpm-15,600 to 17,000 ftAbs on bolt torque,34 to 100 ft/hr ROP. 6/17/2015 Drilling 6 3/4"hole at 12,098',driller noticed on bottom torque quickly increasing.Made an attempt to PU and backream through coal seam(top 12,035'md/bott 12,060'md)and topdrive rotation;stalled,then could not PU at the usual 205K.Had no change in pump pressure or return flow,still had good circulation.;Cont to l� work pipe but unable to cock drilling jars due to low height of topdrive at rotary table(stand drilled down).Added 1 drum NXS lube to suction pit and cont to work Lt.✓ string while;staging single joint on catwalk.PU single and cont to work string while circulating at 341 gpm-3059 psi.Able to jar up and down.Cont to work string alternating pump rates/no pump and;with or without holding torque with topdrive.Reduced pump rate to 253 gpm-1975 psi and cont jar up and down,reducing pump ark" rate on down stroke,increasing pump rate on upstroke;and getting significant better jarring.Pumped a second hi-vis sweep with walnut and cont to work string from 30K to 340K.Have seen a 3°tum in tool face,and a 3'change in heighl;afterjarring and pulling to 340K.From neutral weight of 125K to 340K we have 14'of stretch.From previous up weight of 205K to 340K we have 8'of stretch.;lnspect derrick and drawworks while building a 20 bbl hi-vis lube pill.No issues found in derrick or drawworks.Drill line looks good.All access points to rig floor flagged off.;Spot hi-vis lube pill outside BHA and while holding approximately 19,000 fUlbs torque via topdrive,work drill string with no pump,from 30K to 370K.Cont work with no torque.;lnspect derrick and drawworks with new crew on tour.No issues found in derrick or drawworks.Drill line looks good.All access points to rig floor remain flagged off.;Cont to work string jarring up and down(60K down-340 to 360K up). 270 gpm,1955 psi,30%flow. 2225u max gas @ btm's up(pumps off 3 hrs). No success freeina ojpe.:Halliburton E-line nn Incatjpn._.R/U long bails. Spot E- line truck. Bring E-line tools to floor and R/U same for free point. PJSM w/crews prior to rig up and running. 6/18/2015 With Halliburton a-line equipment RU,MU 1.69"freepoint tool string.PU same and stab in drill string,MU packoff assembly.;RIH to 2200',hole angle at 73 degrees. Tool would no longer travel down drill string.Made numerous attempts but could not get deeper than 2200'.MU 2"circ hose to pump in sub and roll pump to;establish circulation for pumping freepoint tool down drillstring.With pump at idle pressure increased to the point it stalled pump motor.Double check fluid path alignment(ok),attempt to pump;again with same results.Tried second rig pump with same results.Ran pump motor up as far as 3500 psi with no returns and no loss in DP pressure.;POOH with e-line,RD packoff assembly and lay down freepoint tool.PU and MU joint and topdrive.;Bring pump pressure up to 1600 psi and work tool string from 60K up to 340K jarring at 280 to 300K with no loss in pressure or indication of flow.Cont jarring with various drill pipe pressures.;Break off topdrive and lay down single.Install pump in sub,stab freepoint tool with 3 sets roller bars,stab packoff assembly and RIH.At 2332'tool no longer would travel down drillstring.;At 2332'hole angle is 76 degrees.E-line OD is 15/32"and rather heavy.Have second truck on location with smaller a-line cable.;POOH RD packoff and sheaves.Spot second truck and RU same.Hang sheaves,stab freepoint tool with 3 sets roller bars,MU packoff assembly.;RIH with 1.69"freepoint tool on 7/32"e-line.Could not get any deeper than 1920'.Hole angle is 76 degrees.Notify Drilling Engineer and Manager,decision made to POOH and RD e-Iine.;Continue jarring operations w/no circulation. 370k up,30k dn w/soft set dn. Jars firing @ 280k on up stroke and continually diminishing.;Attempt to circulate while jarring, Psi up to 2500 psi w/no circulation.;PJSM,Bring tools to rig floor and rig up SLB cement pump truck to pump down string.;Found 12 bolts sheared on 2 brake pads during inspection. Replace bolts and re tq. Adjust brakes.;PJSM w/SLB. P/T lines 1500/7500(OK). P/U to 340k and park. Stage pumps up in 500 psi increments starting @ 3500 psi. Held each psi 3-4 min before increasing. Pumped a total of 3 3/4 bbls;at 6900 psi the psi dropped to 6400 and stabilized while pumping @.2 BPM. Stopped pumping,psi @ 6150 dropped to 5900 over 5 min. Bleed back 3 bbls(3/4 bbls lost to formation). R/D SLB.;Pumping operations were with fresh water.;Continue with jarring operations. 360k up,40k soft set dn. No movement.;R/U halliburton slickline. Bring tools to rig floor for drift run to simulate running perfs. • • 6/19/2015 RU Halliburton slickline unit.MU 40'dummy string as follows:10'x 2"dummy gun,20'x 1.5"roller assembly,spangs and jars.RIH with assembly to 3237'where assembly started taking weight.;Cont to work assembly down drill pipe from 3237'to 3780'at which point we could no longer work tool downhole.Notified Drilling Engineer and Drilling Manager.Decision made to POOH and RD slickline,;and call out coil unit.;Notified slickline crew,POOH RD and release slickline truck and crew.Staged Halliburton's a-line truck on location.;Re-arrange yard to accommodate incoming coil unit,change to short baits to allow more height hanging injector head/gooseneck assembly.Work drillstring but jars no longer hammering.No movement.;Cut and slip 182'of drill line.;Work drillstring 30 minutes with no movement of string.Jars not hammering.;Continue working pipe,attempting to free. Jars no longer firing up or down. 340k up,90k dn. C/O radiator on#1 MP. Prep location for staging CTU.;Rig service-Grease top drive,crown,drawworks,blocks,brake linkage. 6/20/2015 Cont to complete radiator installation on mud pump#1,strap shoe track equipment and liner hanger/SBE assembly,prep mud products for rig move,clean gen skids,pressure wash derrick and topdrive,;change TD gear box oil,change grabber dies,change floor motor transmission oil,CTU pump truck on location at 10AM, CTU nitrogen truck on location at 15:00,CTU,spare reel and stand on location at;17:00 hrs.Peak crane offloaded spare reel and stand.;PJSM w/Saxon,Peak, SLB and Hilcorp rep. Spot CTU. Set coil skid and install 1.5"spool. R/U and stab coil to injector head. Spot coil pump truck and layout hard line. Set SLB BOP's on floor.;Release Peak and SLB @ 00:00 hrs. Scheduled to return @ 08:00 hrs.;Make up cross overs to 5M flange. Install xo spool to 10M and install SLB BOP'S. Secure BOP's and prep floor for lubricator and injector head install. 6/21/2015 Clean pit#7 and trip tank,housekeeping on pad,cont sorting through Rig 147 connex's while waiting on arrival of SLB coil crew(timed out on hours at midnight)and Peak crane operator.;PJSM with CTU crew,Saxon crew,Peak crane operator and Hilcorp Co Reps.Service hands signed in and made aware of muster areas.;MU 2"line on CTU mudcross and fluid pack all lines with water.Close CTU blinds and attempt shell test.Had leaks on two flanges and one threaded connection.;Pick CTU BOP stack off stump with blocks,remove XO flange from stump,clean and thread tape same.Tighten two flanges on CTU stack.Re-install CTU stack on stump and flange up.;Shell test CTU stack at 250Iow/4000 high for 5 minutes.Good test.Test CTU BOPE at 250 low/4000 high at 5 minute intervals.Witness of testing waived by AOGCC Rep Jim Regg;on 6-20-15 at 10:15 AM.While testing CTU crew hung injector from crane,MU 10'lubricator section and service loop.;Pick injector head and gooseneck to rig floor with Peak crane,transition injector head to topdrive bails with slings and remove crane.RU tuggers,sheave, straps and chainfall in various places to;allow MU of injector head on top of CTU BOP stack.Torque tube loosened and scoped to back of derrick as far as possible. Extremely tight fit but will go.Due to time spent testing and RU,notified;Drilling Engineer of possibility CTU would time out on hours if we make dummy run with circ nozzle.Decision made to MU 2"pert gun and TIH to make pert in drill string.;Held PJSM with CTU crew,Saxon crew and Hilcorp Co Rep.MU SLB's 2"pert gun. 61 shots(1/2"),6 spf,60°phase. Make up flange connection and shell test(test good).;RIH w/coil and tag @ 11,962'setting down 1K. No obstructions observed getting to depth.;POOH F/11,962'-T/11,690'MD to pert depth. 28K up and parked in tension.;Drop 1/2"aluminum ball. Pump dn @.7 BPM,3300 psi. Observed psi increase to 3600 then fall back to 3250 @ 13.6 bbls into 22 bbl displacement. Continue pumping with no other indicators guns fired.;Pumped a total of 23.5 bbls w/no change. Drop 2nd 1/2"(steel)ball. Pumped a total of 31 bbls w/no indicators ball seated. Attempt to circulate thru perfs in HWDP w/no circulation.;Psi up to 2300 w/no retums.;POOH F/11,690'-T/200'w/2"guns on coil. Safety meeting w/SLB and rig crews for handling guns. Continue POOH into lubricator,B/O flange and disconnect from stump.;Found guns had fired as designed. B/O and UD spent guns. 6/22/2015 LD 2"Schlumberger pert gun.Released CTU crew for required 8 hour rest.Remove 5K flange assembly from drillstring stump and MU TIW,headpin and circ hose. Attempt to break circ at 2700 and 2800 psi;psi numerous times with no success.Lay out 4 1/2"liner and number same for run tally,Rig cont maintenance on#1 gen l set.Shipped out directional tools,DD-MWD and Mud Loggers rigging down units and;are being released.Contacted Halliburton shop for severing tool.Round up ZJ XO's and build firing head at Halliburton shop.CTU crew and Peak crane operator on location at 16:00 hrs and 17:00 hrs.Prep;to hang off CTU injector and BOP 5 stack on crane and place drillstring in tension for severing.;N/D and set back Injection head. Secure w/crane. P/U to 240k(222k string wt)and park in slips. Install safety clamp on drill pipe. Dress coil tbg w/2"Halliburton dcst. M/U coil to stump.;RIH F/surface to set depth of 11,679'MD. PSI up to 3800 psi @ 1.4 BPM. Observed slight psi drop to 3400 psi. Slight returns @ 1.4 BPM(10%returns)indicating severing tool fired;POOH F/11,679'-T/surface.;N/D injection head and 014 verified severing tool fired(good). N/U head and blow down coil w/nitrogen. Bleed down nitrogen before nipple down. 6/23/2015 Blow down coil with Nitrogen,stage BOP stand on rig floor,hang injector assembly from crane standing on pipe rack on rig floor.;MU topdrive on drillstring,attempt to break circ with rig pump from 2800 to 3500 psi with no indication of return flow.PSI bleeds off slightly.Work string up to 320K with and without torque.;Work string with and without pressure on drillstring.Notify Drilling Engineer and Manager,decision made to RU coil pump unit to rig and attempt pumping higher pressure. RU coil pump truck in;rig cellar mezzanine. Flood coil and circ lines with 9.3 mud from pits.;CTU pump truck pumping at 1 bpm,pressure steady climbed to 3450 psi and broke over,increased to 3500 psi,then fluctuated from 3450 to 3500 psi with no return flow(injecting).Increased rate;to 1.5 bpm and pressure increased to 3670 psi.Cont pumping with pressure fluctuating from 3615 to 3670 psi.While pumping,obtained stretch parameters:135K to 340K=7.6'of stretch,205K to 340K;=4.7'of stretch,(previous was 135K to 340K=14'stretch,205K to 340K=8'of stretch).Pumped a total of 23 bbls away with no return flow and shut down CTU pump.Cont to work drillstring t/360k.;Add in in 15'pup.Continue work drill string f/82k under(10k) 1/163k over(360k)with and without torque also bring on SLB pump trk and pressure up V 3800 psi w/4 bbls&pump away 21 bbls @.3;bpm w/no returns dn pump monitor pressure,bleed off pressure, pressure returning 1400 psi ballooning. Bleed off 2nd time pressure returned V+-1985 psi.Moved pipe up hole+-10'and found;sweet spot w/rotation and attempted to gain circ w/pump truck had slight circ briefly then everything locked back up.;Continue work pipe f/82k under(10k) V 163k over(360k)with and without torque also bring on SLB pump truck and pressure up V 3800 psi still experencing ballooning w/2-3'pipe move movement.;Coil crew back on location. 240K (222k string wt)in slips. UD 10' lubricator extension. N/U SLB stack directly to injection head due to height restrictions in derrick(derrick board);PT injection head,SLB stack and coil. 250/3500 w/15 min hold(test good).;M/U Halliburton 2"DCST on 1.5"SLB coil. N/U injection head assy onto drill string.;RIH w/2"DCST to set depth of 11,450'. 6/24/2015 Set Halliburton 2"DCST via SLB 1.5"coil on depth @ 11,450'MD. Psi up @.5 BPM to 4,100 PSI WI no indications of fire. Psi leveled off pumping.1-.3 BPM. Total of 7.7 bbls pumped away.;Shut down and bleed off psi. Ramp up pumps to 4k w/no change or indicators DCST fired. Bleed off psi.;Pooh w/coil;Break off injector head DCST fired as designed. Stage injector head&Bopes on rig floor w/crane.Remove TIW and XO from 20'stump and install elevators.;Resume work drill string f/82k under(10k) 1/163k over(360k)with and without torque also bring on SLB pump truck and pressure up V 3800 psi w/no pipe movement.;Close bag pressure up annulus V 1400 psi w/injection @ 2.6 bpm @ 1360 psi w/total 10 bbls injected while monitoring DP pressure and 7-5/8"X 10-3/4" annulus.;Resume work drill string f/82k under(10k) V 163k over(360k)with and without torque w/no movement.;R/dn short bails and install long and head pin and run hard line V pump trk. P/U 305k and park.;PT lines 400/7500(test good). Pump @.4 BPM to 6400 psi before breaking over. Inject @.4 BPM,6400 psi. Inc rate.5 and psi up to 7500 psi. Shut down. 26k loss in string wt.7.7 bbls total;Bleed off psi. P/U 360k and park. Able to inject @ 1 BPM,6700 psi. 6 bbls pumped. Shut down and bleed to O. 40k string loss. R/D hardline and work pipe.;Work pipe P/U 360k,6/0 10k with and without torque w/no movement.;P/U 210K and park in slips w/safety clamp. R/U coil. Dress coil w/Halliburton 2.5"RCT on SLB 1.5"coil. Drift flange adapter and xo's w/2.54"drift. RCT is pressure fired 1800-2400 psi.;No disconnect run on coil. P/U and N/U coil on 20'stump. Unable to pass tools through TIW and XO's. Set dn 2k several times attempting to pass. Unflange and work pass. Reflange coil.;RIH w/Halliburton 2.5"RCT via SLB 1.5"coil to 4996'MD. Gen set on coil went down.;Coil generator went down due to fuel supply. Repair and power up coil unit. • 6/25/2015 RIH w/Halliburton 2.5"RCT via SLB coil F/5000'-T/7805'MD CTM.;Fire RCT(@ cut depth 7800'CTM w/2800 psi. Observed a psi drop to 525 psi w/flow back to shakers. Continue circulating @ 2.5 BPM while pulling out of hole w/coil.;Unflange injector head and BOPE inspect cutter(Good now blow back or stage) remove same.;Restab BOPE and injector.;Blow dn coil w/N2.;Remove injector head and bopes and transfer load to crane and stage on rig floor. Install elevators ry� r►7 and latch 20'stump and slack off, remove TIW and flange XO.;M/up TDS and pull pipe in to 230k tension.Break circ @ 2.6 bpm(41481 psi. Finish circ btm up w'' ��JJ�� staging rate U 350 gpm(lots fine coal&wall cake over shakers).;Start working torque into drill string and finished off cut @ 224k. Set slips and inspect derrick, TDS and crown(ok)chk weights while pumping up/dn/rot=82k/64k/70k(seems light?).;Continue circ and rotate and reciprocating pipe while r/dn coil tbg injector head and BOPE and circ lines from rig fl000POOH F/7800'-T/surface w/no obstructions. Hole took 6.6 bbls over calculate9Silj. Pulled a total of 249 jts and cutoff jt(14.2'in length). UD all 20 Turbulizers on trip out.;Pull wear bushing,drain stack and install test plug. Flush and fill BOPE w/H2O. Shell test 4000 psi.;Test BOPE-T3 Energy 11"5K Class V stack. 250/4000(250/2500 annular). 5 min low/10 min high as per Saxon. Test as follows-#1 annular-#2 uppr rams,mez �> kill,CMV 12,3,dart,lwr IBOP,;#3 upr rams,kill HCR,choke HCR,TIW-#4 upr rams,kill man,choke man,TIW-#5 lwr rams-Drawdown 3000 start psi,drw dn 1500,21 secs 200 psi inc,98 sec full charge. 2650 4 bottle avg,;#6 blind rams,CMV 4,7,8-#7 blind rams,CMV 6,5,13-#8 blind rams,CMV 9,12. AOGCC-Jim Regg waived witness on 6/23/15 @ 11:55 am. 6/26/2015 Continue testing Bopes 250/4000 psi as per AOGCC regulations&continue chg/out TDS hyd mtr.;Strap and tally clean out Bha and continue chg out TDS hyd mtr and chg out wash pipe.;Service rig finish TDS hyd mtr chg out and function test(ok).;Re set test plug and test bag to 4000 psi as per permit to drill(good). It was only tested to 2500 psi during test.Rig do test equipment and set wear ring.;M/up C/out Bha=6-3/4"RR mill tooth bit+bit sub w/float+WBS @ 6.5"+(2)Dc's+ XO+(3)jts 4-1/2"HWDP+XO+jars+Xo+(5)jts 4-1/2"HWDP=350.22'.;Rih to 6550'(shoe @ 6785') fill pipe every 2000'stopped @ 1279'to hammer up wash pipe.;Cut and slip 114'drilling line. CBU while cut and slip. Pump @ 153 gpm,267 psi. Inspect brake bands and adjust.;Parameters @ shoe 95k up,52k dn pumps off. 88k up,52k dn,65k rot,6.7ktq,20 rpm w/135 gpm. Continue RIH F/6550'-T/7767'set dn 7k then ream past tight spot©7767'-7780'.;P/U single and wash dn tag T.0 F @ 7805'no rotary w/10k set dn. P/U and verify tag depth. 115k up,60k dn,85k rot. Jeff Carter(Baker Fishing)verified tag.;UD single. Circulate and condtion mud while reciprocating pipe F/7790-TI 7730'MD. Pump @ 4.5 BPM,535 psi,20 rpm,5.8k tq,22%flow. Observed fine coals @ shakers but nothing significant.;POOH F/7790'-T/2303'w/6 3/4"cleanout assy.; 6/27/2015 Continue pooh w/clean out Bha.;Udn inspect Gout bha(ok).:P/up fishing bha#1= 6-3/8"0/s w/cut lip guide dressed w/4-1/2"basket grapple and MCP and POS +jars and accelerator.;Rih U shoe @ 6734'.;Circ btm&establish parameters adjust torque dn on TDS U 16k.;Run in open hole T/7728'kelly up and wash dn 117790' circ.clean&establish parameters.;P/up single wash dn engage fish @ 7805'w/2'of swallow P/up 1150k over bleed jars and set grapple w/80k over.;Start firing jars f/80k over and stage jar licks U 100k over w/and with out pressure. Apply tq and work string but lost fish on 3rd dn stroke. Re-engage fish cont jarring w/no rotation.;lnspect derrick,drawworks,and traveling equipment(good).;Continue jarring operations w/100k over(max)then straight pull to 360k after jars fired. Jar dn w/no change.;Perform post jarring derrick inspection. Inspect derrick,traveling equipment and drawworks(good). 6/28/2015 Psi up to 4000 psi and burst rupture disc on circ sub. Establish circulation @ 2.6 BPM,535 psi,12%flow.;Bring slickline tools to rig floor. M/U xo's,hang sheaves, spool slickline and makeup tools. Largest OD 2.238"on btm centralizer.;Finish R/up and stab lubricator and r/up circ hose.Test lubricator and circ hose U 50001700H psi(ok). RIH#1- 1-3/4"bailer w/2.238"cent&1-1/2"roller stem pump tools dn at 2.6 bpm,;had to increase rate U 3.6 bpm @ 4000'sat dn @ 7644' wlm twice(2nd top dc)1200#over+1 jar lick to free. POOH reconfigure tools(no roller stem conventional weight bars).;Rih#2&pump dn same clear fishing bha and dn pump Rih U 11250'w/no problems Pooh and r/dn slickline.;R/up E-line w/side entry sub rih#1-w/1-7/16"free point on 2-1/8"roller boogies to 7400' MD.;Work motorized free point tool to QC data and obtain baseline.;Work pipe in 500'intervals dn U 11000'(not free)back up to 10660'(stuck point). Work string F/80k-T/270k.;POOH w/MFT F/10,660'-T/surface. B/O E-line equipment and UD MFT as per Pollard.;PJSM, M/U 1 3/4"DCST on 1 11/16"tool string=rope socket+2 1/8"roller boggies+wt bar+CCL+wt bar+2 1/8"roller boggie+xo+shock sub+shock sub+1 3/4"DCST.;P/U to 250k and park. RIH w/DCST to severing depth of 10,505'WLMD(drill pipe connection). Correlated connection w/CCL log. Fire severing tool w/no indicators of free pipe.;POOH w/E-line. Pulled tight having to work E-line from severing depth to 7700'WLMD. Pulled clean to surface from 7700'.;R/D E-line and UD lubricator. Found 4-6"piece from 1 3/4"DCST was missing from btm of toolstring.;Kelly up and begin jarring operations. 80k dn to 360k up w/and without pumps. No change. 6/29/2015 Continue iarring operations.Continue fire jars Cd)110k over(recommended max of iar lick)and straight pull of 360k(Max of rig)238 over,also break circulation for (6' 30 min @ 2.6 bpm @ 570 psi.;Jarred down and exercised bumper sub w/good-20k dn wt.Attempted work RH torque in to string and shucked grapple. Was successful w/re-engagement.Work 4 1/2 rounds LH trq into string,no movement.;Received orders to cease fish operations. Move forward with sidetrack ops. Cocked jars w/jars firing at close to 200k over w/3rd super lick we shucked grapple.Unable to reengage.;Monitor hole.Static.Circ bottoms up and finish R/D E- line&perform post jarring inspection of rig(ok).;POOH w/fishing BHA#1.;Inspect and L/D fishing BHA#1. Recovered 6"piece that was missing from severing tool. Found in top of grapple. See pic via drilling engineer.;UD all subs and 13/0 crossovers for E-line equipment. Clean and clear rig floor.;PJSM,R/U Weatherford casing. Bring handling tools to rig floor. R/U double stack power tongs and power up. RIH w/774'(26 jts+1 jt stinger). R/D Weatherford casing.;TIH out of derrick F/774'-T/6667'.;CBU @ 6667'MD. 300 gpm,615 spp w/31%flow.;TIH F/6667'-T/7783'MD. P/U 15'pup and set @ 7796' f V MD.;PJSM, R/U cementers. Rack in SLB cementers. M/U hardlines and bring tools to rig floor. Circulate and condition mud during rig up,260 gpm,612 vl spp.;PJSM,flood lines w/3 bbls H2O,PT 1500 low/3300 high,Rig pump 20 bbls 12.5 mud push spacer,SLB pump 27 bbls 16.5 ppg"G"cement,7 bbls 12.5 mud_ push spacer,SLB displaced=84 bbls w/9.3 mud.;Batched up and started pumping @ 02:58. Finished pumping @ 03:26. Under displaced 9 bbls. Put string on slight vac for trip out above balance plug.;Partially R/D SLB cementers. POOH F/7795'-T/7033'MD @ 15 ft/min first 3 stds then 25 ft/min last 8 stds. No issues. 92k up. No disturbance to cmt plug @ 04:23;7033'MD.Drop wiper plug(P/N:152015). Circulate @ 437 gpm,1080 psi. At 3190 stks dump mudpush and slight ( cmt contaminated mud. Cleaned up and shut down. Monitor well(static).;POOH F/7033'-T/5606'MD. V (1" 6/30/2015 Continue pooh w/3-1/2"btc tbg cmt stinger.;R/up power tongs and Clean I/dn and inspect 3-1/2"btc tbg cmt stinger.;Service rig chk end play on TDS also inspected mud pumps cleaned out all suction screens&sumps chk fluid ends.;Strap,tally and P/up M/up bha, 6 3/4"PDC bit,mud motor w/1.5 deg AKO,float sub,DM collar,EWR-P4,,PWD,TM collar,Upload data,check pulser.M/U NMFC,XO,7 jts HWDP,XO,jar,XO,7 jts HVVDP;TIH from 574'to 946'.;Continue to TIH from 946'to 3611',fill pipe.;Tum elevators,strap and tally drill pipe and 20 spiro torq impellers.;Drift,P/U and single in w/96 jts drill pipe from 3611'to 6642',fill pipe @ 4878'.Note:install spiro torq impellers starting @ 3611'on jt#99 and then every 4th jt ran,20 impellers total.;POH and rack back 10 stands from 6642'to 6051',single in the hole with 18 jts DP to 6604'(114 jts total).;Adjust top drive torque,set @ 18,000 fUlbs.Check pipe count to ensure it is accurate.;TIH with stds from 6604'to 6728',fill pipe. M/U 1 std and top drive. Ease out of shoe©6785'. Note:9 bbls under calculated displacement on TIH.;CBU pumping 350 gpm, 1920 psi working pipe just out of 7 5/8"shoe. P/U 95K,SIO 52K,ROT 62K @ 25 RPM torq 7200 ft/Ibs.;RIH from 6790'to 7103', wash from 7103'to 7411'looking for TOC pumping 338 gpm,1950 psi.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3690 bbls Hauled 160 bbls Class II fluid to G&I,Total Class II fluid hauled=7198 bbls 7/1/2015 Continue washing and reaming f/7411'to 7475'rpm 30,torque @ 11.500ft/lbs,GPM @ 340,SPP @ 1950 psi and diff @ 100 psi looking for firm cmt. Started seeing 200-300 psi diff @+-7292';w/PH climbing up U 12.9 and rotten mush cmt at shakers.;Attempt kick off and trough low side f/7475 U 7500'w/tool face @ 180.;Time drill one foot per hr f/7499'1/7505'attempting to build a low side ledge(tool face @ 180)showing up to 10% formation.;Time drill two feet per hr ff7505' V;c U 7509'attempting to build a low side ledge(tool face @ 180)showing up to 20% formation.;Continue to time drill 2 fph f/7509'to 7518',samples show 70% formation,Increase ROP to 4 fph f/7518'to 7524',samples show 90%formation. 160-180 deg tool face.;Continue to time drill 4 fph f/7524'to 7525'.Increase ROP to 6 fph f/ 7525'to 7535'.Sample shows 90%formation,survey indicates 1 deg separation from old wellbore.;Slide f/7535'to 7549'pumping 350 gpm,2140 psi,wob 3k,ROP 40 fph,diff 145 psi. Rotary drill f/7549'to 7572',40 rpm,torq 9200 ft/lbs.wob 4k,ROP 65 fph.;Samples show 80%cement,pump survey, indicating 3 deg separation f/old wellbore,residual cement in sample from rotating,cont to drill f/7572'to 7656'. Increase to 80 RPM,torq 15500 fUlbs.;Drill f/7656' to 7665', PU 158K,SO 50K,ROT 75K.MW 9.2 ppg,59 vis.No losses.;15.07 slide hrs,0.94 rotate hrs. 10.55'above the line,1.34'left of the Iine.;;Hauted 2 bbls cuttings to G&I,Total cuttings hauled=3692 bbls Hauled 178 bbls Class II fluid to G&I,Total Class II fluid hauled=7376 bbls • • 7/2/2015 Directional Drilling 6 3/4"hole f/7665'to 7945'established rotary trend(walking Rt 1 deg pert 00'good,get away from old well magnetic interference so we can see it and.35 deg build per 100').;Up TDS max torque 20,700-20,800 ft/lbs to have horse power for a fight and cease back reaming attempts on conn.just straight pull std let bit ream and ream dn once before conn.;Slides as necessary to maintain direction.Pump tandem 21 bbl Low/Low and High/High sweeps#1 while drilling f/ 7856'U 7906'sweeps back on time w/increase of 50%cuttings.;Continue drilling f/7945'to 8280'pumping 353 gpm,wob 5k,80 rpm,torq 18300 ft lbs.PU 191K, SO 48K,ROT 98K.;Continue drilling f/8280'to 8339'w/15'slides every 100'building back to planned inc 19.5 deg.353 gpm,2420 psi,75 rpm,18600 torq.PU 215K,SO 50K,ROT 90K,MW 9.3 ppg,vis 54.;Pump survey,pump tandem 20 bbl Lo vis/20 bbl 11.7 ppg,460 hi vis sweep#2,reduce pump to 290 gpm w/hi vis sweep thru MWD tools,sweep back 200 stks late with minimal increase in cuttings.;POH f/8339'to 8205',flowcheck well,static.Continue POH to 7963',check crown-o-matic,would not re-set.;M/U topdrive, circulate and rotate pipe,C/O crown saver actuator on drawworks.;Continue POH f/7963'to 7467'above kickoff point with no issues. Correct displacement on trip out.;TIH f/7467'going slow past KOP.TIH to 8280'with no issues. Wash last std to bttm @ 8339'w/no fill.1 bbl under calc displacement on trip in.;Continue drilling f/8339'to 8402'pumping 353 gpm,2410 psi.80 rpm,torq 18600 ft/lbs,ROP 60 fph.MW 9.4 ppg,vis 56.ECD 11.15 ppg.;Continue drilling f/8402'to 8671'pumping 353 gpm,2450 psi.WOB 3-5K,75 rpm,torq 18800 ftAbs.Slide 15'every 120'due to walking 1 deg right and dropping 1/4 deg per 100'.ROP 80 fph.;PU 235K,SO 45K ROT 82K.Off bttm torq 19600 ftlbs.MW 9.4 ppg,vis 58.ECD 11.2 ppg.No losses. 3.67 slide hrs,10.57 rotate hrs. 6.90'below the line,4.80'left of the line.;;Hauled 36 bbls cuttings to G&I,Total cuttings hauled=3728 bbls Hauled 234 bbls Class II fluid to G&I,Total Class II fluid hauled=7610 bbls 7/3/2015 Continue directional drilling 6 3/4"hole f/8671'to 9455' hitting max torque of TDS start lube and bring concentration up 1%.;Change out high pressure hyd bypass valve on tds due to possible leaking,torque dn f/20k U 13,800,continue slides as necessary to maintain direction.;Pump 3rd tandem 20 bbl Lo/Low and Hi/High sweeps while drilling f/8898'1/8960'. Sweeps back on time but strung out w/increase of 65%dump same.;Swap out centrifuge due to possible main bearings going out and not making the cut needed. Note:after increasing lube in system to 1%P/U 170K,SO 68K,ROT 105K. MW 9.4 ppg,vis 57,ECD 11.17 ppg.;Pump survey, Pump 4th tandem 20 bbl Lo/Low and Hi/High sweep,sweep back on time w/10%increase, dump weighted sweep retums. Flowcheck well, static.;Decision made to pull to shoe to C/O weak Rainier drive motor on top drive(due to limited max RPM @ 65)and to cut and slip drilling line. Short trip f/9455'to 6725'into 7 5/8"casing.;No issues on trip to shoe,correct fluid displacement on trip out.;Flowcheck well for 10 min,static.MN FOSV and topdrive. Cut and slip 100'drilling line,re-set and test crown saver.;Service crown,blocks,drawworks and driveline,inspect brake linkage while rig mechanic removing Rainier drive motor f/top drive.;Remove Rainier drive motor on topdrive and install new drive motor.;1.8 slide hrs,10.18 rotate hrs. 1.84'above the line,6.78'left of the line.;;Hauled 43 bbls cuttings to G&I,Total cuttings hauled=3771 bbls Hauled 317 bbls Class II fluid to G&l,Total Class II fluid hauled=7927 bbls 7/4/2015 Continue chg/out of TDS hyd mtr.Pulled inside 7 5/8"casing,function and re-adjust torque and pressure settings also chk TDS end play(none). Rig on dn time.;Nose out csg shoe and function test(ok).Rih w/no problem to sidetrack depth. Continue RIH,set dn 20k and over pull 30k(run back through(ok)@ 7473'. Continue RIH set dn 15k P/up w/no;overpull @ 8857'run back through(ok)and just bobble at 8878'wipe same ok. Rih and tag 31'fill @ 9424'w/60k over to get out. Kelly up attempt ream TDS dumping oil out bypass w/high kelly.;Note:SO1 report submitted for TDS dumping oil.;Shut dn reaming. Rack back std,lower TDS. Circ btm up and inspect and trouble shoot same. Well unloaded significant amount of cuttings and bypass quit dumping.;Wash and ream f/9424'U btm 9455'.;Continue directional drig 6-3/4"hole f/9455 U 9830'sliding as needed to maintain direction.WOB 5k,80 rpm,torq 15000 ft/lbs,PU 198K,SO 78K,ROT 121K. Note:start drilling coal top @ 9820';Service top drive.;Continue directional drilling f/9830'to 9890'working thru coal f/9830'to 9860'taking 1'-2'bites and cleaning up same.Note 1013u gas f/9822'.;Increase in torq f/16500 to 17500 f1Abs,pump 5th tandem 20 bbl Lo/Low and Hi/High sweep. Rotate 80 rpm,work pipe,sweep back on time w/60%increase, dump weighted sweep retums.;Continue directional drilling f/9890'to 10020'sliding as needed to maintain direction,351 gpm,2656 psi,WOB 3-5k,60 rpm,15300 ft/bs torq. PU 176K,S/0 70K,ROT 105K.MW 9.4 ppg, ECD 10.95.;Cont.directional drilling f/10020'to 10182' sliding as needed to maintain direction,TDS torque display on Pason failed,disabling auto driller. Cont.w/TDS pressure gauge to read torque.;Pump 6th tandem 20 bbl Lo/Low and Hi/High.circulate,straight pull,then rotate down. Torque @ 18000 fUlbs,install hydraulic sensor to run off TDS hyd torque gauge,operational with auto driller.;WOB 5k,70 rpm, Torq 16600 ft/lbs.PU 183K,SO 75K,ROT 105K,MW 9.4 ppg 56 vis,ECD 10.81 ppg. 2.31 slide hrs,8.31 rotate hrs. 2.42'above the line,1.33'right of the line.;;Hauled 25 bbls cuttings to G&I,Total cuttings hauled=3796 bbls Hauled 155 bbls Class II fluid to G&I,Total Class II fluid hauled=8082 bbls 7/5/2015 Finish pumping tandem lo/low and Hi/High 20 bbl sweeps#6 around @ 10182'. Sweep back on time with 25%increase.;Continue directional drilling 6 3/4"hole f/ 10182'to 10447'w/slides as necessary to maintain direction(also chg/out saver sub on connection)pump tandem to/low and hi/high.;20 bbl sweeps around while drilling last std dn.sweep back 5 bbls late w/increase of 50%finish circ btm up.;Attempt Pooh for short trip f/10447'std back one std and flow chk well flowing @ 2.6 bph circ btm/up chk mud weights.Max gas 303 units dn pumps flow chk well flowing @ 5 bph.;Circ and weight up in.2 ppg increments f/9.4 ppg U 9.6 ppg w/high gas of 460u @ BU,continues to flow @ 5 bph,bring wt up to 9.8 ppg,w/good 9.8 ppg in/out,flowcheck well, flowing 1.8 bph,;CBU, 330 gpm,2300 psi, ECD 11.14 ppg, BU gas @ 451u. Flowcheck well 15 min,flowing 1.25 bph,increase MW f/9.8 ppg to 9.9 ppg.ECD 11.36 ppg.BU gas 460u,flowcheck well 20 min,;increase MW f/9.9 ppg to 10 ppg. 284u gas @ BU,w/good 10 ppg in/out. Flowcheck well f/20 min,flowing 1 bph,CBU,330 gpm,BU gas 654u.ECD 11.5 ppg.;Flowcheck well f/15 min,flowing 5 bph.Notify town engineer,decision made to drill 200'+-to drill past next coal interval©projected depth of 10451'.;Make connection©10445',attempt to rotate,topdrive leaking hydraulic oil,cannot breakout std w/topdrive,break 3 singles out in mousehole using rig tongs and UD same,giving room to work string.;M/U topdrive to string,circulate and work string and identify leak is coming f/TDS K strainer bypass.Top drive motor has failed. Continue to circulate and work pipe.;No gains or losses while circulating .37 slide hrs,4.62 rotate hrs. .12'above the line,2.52'right of the line.;Hauled 20 bbls cuttings to G&I,Total cuttings hauled=3816 bbls Hauled 250 bbls Class II fluid to G&l,Total Class II fluid hauled=8332 bbls 7/6/2015 Circulate and work pipe @ 10390',increase mud wt f/10.0 ppg to 10.2 ppg,and circ until 10.2 ppg in and out(ok).;Dn pump and monitor flow initial flow @ 7.1 bph, 5min=5.3 bph, 10 min=2.6 bph,15 min=2.1 bph,20 min=1.4 bph,25 min=1.0 bph, &30 min=.7 bph.;Circ complete round w/235 units gas at btm up and even MW @ 10.2 ppg.;Dn pump monitor flow while brk out of std. TDS saver sub broke remove clamp,&remove saver sub from stump&reinstall on TDS pull one std&install clamp.;Pooh 5 std flow chk well,static.Continue pooh U 6986'and monitoring displacement closely,2 bbls over cal.and no hole issues.;Rotate and reciprocate pipe f/7048'U 6986'and circ STS w/10%increase in cuttings at btm/up.;Continue pooh U inside shoe @ 6680'grab std w/possible wash out in conn. Rih brk,L/D and inspect same,confirm both jts washed.;Monitor well on trip tank, chg/out TDS,remove hyd IBOP and saver sub,R/D service loop,remove kelly hose U top drive.set in cradle,unpin from blocks. Remove same from rig floor.;Set replacement TDS on rig floor,pin blocks,remove f/cradle,M/U service loop, hyd IBOP,saver sub and kelly hose.Purge air f/hyd lines,torq saver sub and hyd IBOP,install clamp.;lnstall bails and elevators, begin testing top drive.Well has slight seepage,3 bbl losses in 12 hrs.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3816 bbls Hauled 0 bbls Class II fluid to G&l,Total Class II fluid hauled=8332 bbls • S 7/7/2015 Continue to test and inspect TDS after install while parked in 7 5/8"casing @ 6679'.Monitor well with trip tank. Topdrive seized up during function testing. Disassembled upper section of topdrive;and raised quill shaft assembly. Found two guide pins missing which allowed a threaded section to backout and seize quill shaft.Recovered one guide pin from topdrive just removed,and had another;delivered to rig from Saxon yard.Installed pins,re-assembled topdrive.Function checked and rotation appears to be working properly.Installed IBOP,saver sub and clamp.;Finish M/U saver sub clamp,Install kelly hose,Test TDS,UD FOSV and head pin.M/U topdrive,set max torque to 21000 ft/lbs.Circ air from lines,pressure test kelly hose and hyd IBOP to 3200 psi.;Monitor well using trip tank,well took 3 bbls f/06:00 to 21:30 hrs,.2 bph.;M/U 3 singles previously UD,RIH just out 7 5/8"shoe @ 6850',M/U top drive,pump 320 gpm,70 rpm,9000 ft/lbs torque. No issues with top drive.P/U 111K,S/O 55K.;TIH from 6850'to 8591'with no issues.3 bbls under calculated displacement. Rig off down time @ 23:00 hrs being back @ wiper trip depth of 8600'.;Reciprocate and rotate pipe 70 rpm,11,400 ft/Ibs torque,CBU 313 gpm,2200 psi.145u gas @ BU.Pump 20 bbl hi vis sweep around,back at calc stks w/15%increase in mostly sand w/small pieces coal.;TIH f/8591't/10326',wash and ream last 2 stands to bttm.No fill.TDS torque 14500 f/lbs, no increase in torque when P/U string.P/U 205K,S/O 70K,ROT 110K.TIH 3.5 bbls under calc.displacement;Directional drilling 6 3/4"hole f/10447' to 10571'pumping 320 gpm,2540 psi,3-5k wob,65 rpm,14600 f/lbs torq.work thru projected coal f/10451'to 10461'taking small bites and back reaming.;Note: @ BU hole unloaded,200% increase in cuttings,90%1/4"in size thin coal pieces,gas peaked @ 2527u,cutting MW f/10.2 ppg to 10 ppg with centrifuge and water to lower ECD.;P/U 190K,S/O 75K,ROT 108K.MW 10.1 ppg in/out.vis 65,ECD 11.6 ppg.No losses. 1.26 rotate hrs,.12'above the line,2.52'right of the line.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3816 bbls Hauled 0 bbls Class II fluid to G&I,Total Class II fluid hauled=8332 bbls 7/8/2015 Cont directional drilling 6 3/4"hole from 10571'to 10,821'.Sliding wob 2K,323 gpm-2514 psi,117 to 200 psi diff,7 to 21 ft/hr ROP.Rotating wob 5K,323 gpm-2657 psi,65 rpm-15,700 ft/lbs on;bott torque,66 ft/hr ROP,MW 10.0 ppg/vis 60,ECD's at 11.5 ppg,BGG 50 units,connection gas+/-400 units.Obtain survey at 10,821'.Up wt 210K,dwn wt 75K with no rotation,just pumping.;At 10,821'pumped tandem sweeps(lo wt to vis/hi wt hi vis)and worked drill string.Had 50% increase in cuttings to surface of very fine sand and coal.ECD's down to 11.1 ppg.Circulated until clean.;Pumped at 323 gpm-2388 psi,65 rpm-15,100 ft/lbs off bolt torque.;Cont directional drilling 6 3/4"hole from 10,821'to 10,927'.Sliding wob 2K,323 gpm-2454 psi,50 to 82 psi diff,10 to 20 ft/hr ROP.Rotating wob 5K, 323 gpm-2574 psi,65 rpm-15,200 ft/Ibs on;bott torque,80 ft/hr ROP,MW 10.0 ppgNis 55,ECD's at 11.1 ppg,BGG 90 units,connection gas+/-700 units.Have ` added 1 drum NXS lube last 12 hours.;Cont directional drilling 6 3/4"hole from 10,927'to TD a 11200',isamples @ TD indicate 50%siltstone,50%coal,pumping r J 322 gpm,wob 5k,65 rpm,16200 fi/Ibs torque,ROP 25-40 fph.;P/U 220K,S/O 80K,ROT 117K,.MW 10 ppg,vis 56,ECD 11.28 ppg,no losses.BGG 30u. ?jam 2.12 slide hrs,13.88 rotate hrs.;Pump final survey(6.42'below the line,7.34'right of the line which puts us 102'from Blossom PB1 at TD)and get SPR's.Pumped tandem 20 bbl low vis/20 bbl hi vis,11.6 ppg sweep around.;sweep back 300 stks late with 25%increase of mostly small fine pieces of coal,dumped weighted sweep returns,circulate hole clean,flowcheck well,static.;POH on elevators from 11,200'to 9699'with no issues or overpulls.Hole fill exactly as it should be.Up wt coming off bottom 235K,down wt 85K.;;Hauled 32 bbls cuttings to G&l,Total cuttings hauled=3848 bbls Hauled 238 bbls Class II fluid to G&I,Total Class II fluid hauled=8750 bbls 7/9/2015 Cont pulling wiper trip from 9699'up to 6787',bit just outside 7 5/8"casing shoe.No issues during trip,hole took 3 bbls over calculated.Released sample catchers.;Pumped a hi-vis sweep at 6787',322 gpm-2000 psi,20 rpm-7200 ft/lbs off bottom torque.Had a 25%increase in cuttings with sweep to surface.;Tripped in hole on elevators from 6787'to 9021'and filled pipe.Tripped in hole from 9021'to 11,136'with no issues.At 11,136'MU last stand,washed to bottom while filling pipe and had no fill.;Wth pipe full,pumped a tandem lo wt-low vis/hi wt-hi vis sweep around with a 50%increase in cuttings with sweep to surface.280 gpm-2085 psi,60 rpm-17,300 ft/lbs off bolt torque.;Had a max of 2799 units trip gas at bottoms up.Checked for flow-static.;POOH on elevators from 11,190'to 7 5/8"casing shoe,260K up wt coming off bottom,parked the bit at 6788'.No issues during trip.Hole took 3 bbls over calculated displacement.:Pumped a 20 bbl hi-vis sweep, 325 gpm-1936 psi,20 rpm-7400 ft/Ibs off bott torque.Had a 10%increase in cuttings with sweep to surface.Checked for flow-static,pumped dry job.;Cont POOH from 6788'(inside casing)to 574'(Layed down all 20 spiro-torque subs.)Hole took 4.3 bbls over calculated displacement from shoe.Flowcheck well,static.;Rack HWDP,jars and flex collar in derrick,pull corrosion ring,download data,UD TM collar and PWD. Inspect mud motor and bit,close blind ram,UD and grade bit, 1,2,Wf,G,X,I,NO,TD.;M/U single w/stack jet tool,open blind ram,flush stack with fresh water.Pull 9"ID wear bushing.Operate rams and flush out ram cavities.;Service blocks,floor equipment,crown and drawworks.Inspect drawworks brakes.;R/U test equipment with 4 1/2"test joint,flood stack and lines with fresh water.Shell test BOPE to 250/4000 psi.;;Hauled 2 bbls cuttings to G&l,Total cuttings hauled=3850 bbls Hauled 178 bbls Class II fluid to G&1,Total Class II fluid hauled=8748 bbls 7/10/2015 Test all BOPE at 250 low f/5 minutes,4,000 high f/10 minute intervals.No failures.Koomey drawdown:system psi-3050,psi after closure-1500,200 psi attained in 23 seconds,full psi attained;in 99 seconds,4 nitrogen bottles at 2650 psi.Total Safety on location at 07:00 and calibrated/tested gas detection equipment.AOGCC c V Rep Bob Noble on location at 06:00 to witness testing.;Remove test plug,drain water from stack,installed wear ring and closed upper annulus valve.Peak cleaned Q D out cellar box.Rig crew re-aligned choke manifold valves and RD test equipment.;Held PJSM and MU logging BHA as follows:Varel 6'"V513PDHRU PDC bit(re- �J run)jetted with 3x10's and 4x9's,5"motor with 1.5°bend(re-run),float sub,DM collar,EWR-P4 collar,ALD collar with;5.625"stabilizer,CTN collar,PWD tool,and TM collar.Uploaded MWD,shallow tested tools(OK),loaded RA sources.MU NM flex DC,XO,7 jnts HWDP,XO,jars,XO and 7 jnts HWDP(599.68').;Cont to TIH on 4 1/2"DP from 599'to 1716'.;Cont TIH on DP from 1716'to 6809'just out 7 5/8"shoe,fill pipe @ 2500'and 5200'.2 bbls under calculated displacement on trip to shoe.;CBU pumping 320 gpm,2300 psi,rotate 60 rpm.120u gas @ BU,no increase in cuttings @ shaker.;PJSM,pull 1 std,park inside shoe @ 6751',M/U FOSV and topdrive.Monitor well w/trip tank.Slip and cut 105'drilling line.;Service draworks,brake linkage and rig motors.;Cont to monitor well,C/O TDS hydraulic motor w/brand new motor due to increase in K-strainer flow,test same.Re-set and test crown saver,UD FOSV;TIH f/6751'to 7118,M/U top drive,check RPM with string,93 rpm,0 psi on K-strainer.Continue TIH V 7118'to 11082'w/no issues,fill pipe @ 8962',wash and ream last 2 stds to bttm @ 11200';no fill.3.6 bbls over calculated displacement on TIH.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3850 bbls Hauled 0 bbls Class II fluid to G&I,Total Class II fluid hauled=8748 bbls 7/11/2015 Circulate bottoms uo Cdr 11.200'.322 gpm-2473 psi,60 rpm-18 to 20K ft/lbs off bolt torque on up stroke,11 to 13K on down stroke(no spiro-torques in string),had 2500 units gas at bolt up.;With gas down to 50 units pumped a tandem sweep with a 50%increase in cuttings with sweep to surface.Obtained SPR's then cycled pumps as per MIND Rep to put tools into logging mode.;Start MadPass logging up hole from 11,197'to 10,073'.Logging at 225 ft/hr.Up wt 125K off bottom,321 gpm-2278 psi,60 rpm-15,400 ft/lbs off bolt torque after adding 2 drums NXS lube to suction pit.;Continue pulling up hole making MadPass from 10,073'to 8468'@ 225 fph,pumping 320 gpm,2230 psi,60 rpm, survey every stand pulled.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3850 bbls Hauled 185 bbls Class II fluid to G&l,Total Class II fluid hauled=8933 bbls 7/12/2015 Continue pulling up hole making MadPass from 8468'to 7602'@ 225 fph,pumping 320 gpm,2230 psi,60 rpm-12,100 ft/lbs off bolt torque, surveying every stand pulled,Up wt 94K,BGG 9 units.;MW 10.0 ppg,ECD's 11.2 ppg,no issues during logging,hole in good condition.;Cont to POOH on elevators from 7602'to 6787' with no problems.Up wt 135K with no pump.BHA pulled smooth into shoe.Flow check was static.Pumped dry job and dropped 2"drift with wire.;Cont to POOH racking back 4 1/2"DP in derrick,from 6787'to 5858'.;At 5858'turned elevators,held PJSM,checked for flow(static).;Cont POOH and lay down 4 1/2"DP from 5858'to 599'at HWDP,(LID total of 170 jts DP w/97 stds in derrick)flowcheck well,static,4 bbls over calculated displacement on trip out of the hole.;P/U 4 jts HWDP. Rack 9 stds HWDP in derrick,Retrieve drift @ jars,L/D XOs,jars and flex collar.PJSM,UD source.Download data.UD LWD,MWD tools,float sub,mud motor and bit.Same bit grade;Clear and cleanup rig floor,R/U to run 4 1/2"Production liner.PJSM with Weatherford,Rig crew,Tool pusher and DSM.;Inspect shoe track for debri,baker lock and MU shoe track,check float operation.P/U and RIH with 4 1/2"DWC/C-HT 12.6#L-80 production liner per tally following wellplan to 813';Install free floating centralizers on every jt,Fill on the fly and every 10 jts ran,optimum M/U torque 6200 f/lbs.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3850 bbls Hauled 270 bbls Class II fluid to G&I,Total Class II fluid hauled=9203 bbls • • 7/13/2015 Cont P/U and RIH with 4 1/2"DWC/C-HT 12.6#L-80 production liner f/813'to 4574'.Top filling on the fly and completely filling every 10 joints.Ran 112 Hydroform Centralizers(1 per jnt).;Ran 5 total RA marker pup joints.MU torque at 6400 ft/Ibs.;MU sealbore extension,removed air slips and set SBE in table.Removed lift sub and PU HRD-E,ZXP,RS,Flex-Lock 5 1/2"x 7 5/8"hanger assembly.PU and MU the 2 3/8"liner wiper plug run tool;extension and MU same on bottom of hanger. MU liner wiper plug onto plug running tool.Stabbed assembly into SBE and MU hanger to SBE.RD and released Weatherford casing crew and tools.;Slacked off and removed protective wrap form hanger and packer.Mixed and poured PalMix and allowed to set up while clearing rig floor of excess tools and equipment.;LD lift sub,MU 3 1/2"x CDS-40 XO,MU one stand HWDP from derrick.Up wt 44K,down wt 31K.MU topdrive and circulated 75 bbls(just over one string volume)at 5 bpm-402 psi.;Cont to RIH with 8 more stands HWDP(total 18 joints)followed with 4 1/2"CDS-40 DP from derrick.TIH from 5195'to 7 5/8"shoe at 6780';MU �?r topdrive and break circ at 5 bpm-567 psi.Reduce topdrive torque to 6500 ft/Ibs(max liner MU torque)and attempt to rotate.Could only rotate while reciprocating string.No pump=;Up weight 73K,dwn weight 45K.5 bpm=up weight 65K,dwn weight 41K.Turned topdrive torque up to 10K to accomodate 3 1/2"IF connection on liner run tool.Circ 1 1/2 string volumes.;10 rpm=7200 ft/Ibs,20 rpm=7200 ft/lbs,30 rpm=7300 ft/lbs off bottom torque.;Exit intermediate shoe and cont RIH + e from 6785'to 9000'@ 60 fpm with no issues,fill on the fly and every 10 stds. P/U 119K,S/O 48K.;CBU,Pumping 226 gpm,730 psi,pump on P/U 110,S/O 49K, 223u gas©BU.;Continue to P/U and RIH with production liner from 9000'to 11144',20k setdown @ 10350',M/U top drive,pump 112 gpm,700 psi and work thru cfiVekv coal.30 bbls under calc displacement on TIH;M/U last stand with cement head,P/U 200K,S/O 70K.M/U top drive,Stage pump to 112 gpm,615 psi,P/U 190K, S/O 65K.increase pump to 200 gpm,865 psi,wash to TD @ 11,200',;start seeing losses @ 25 bph increasing when working pipe past 11,195'with no retums,P/U past 11,195'to 11,176'and regain flow back.R/U cementers.Note max gas while circulating 1088u;PJSM while working pipe f/11,190'to 11,176',circulating with intermitent retums.As long as we reciprocated pipe we had returns.Lost 60 bbls total during circulation.;SLB pumped 5 bbls water to flush lines,then 5 bbls to fill lines.Shut in cement head and PT lines at 1000 and 5500 psi.Rig pumped 21 bbls 12.5 ppg Mud Push II at 3 bpm-800 psi,lined up cement head;to SLB.SLB pumped 175 bbls(738 sx)15.3 000 Class"G"Fasv Blok cement 4.5 bom.1000 to 300 psi with intermitant returns and shut down.Baker released dart,then SLB displaced with 10.0 ppg 6%;KCL mud at 6 bpm-200 psi ICP.Slowed to 2 bpm with 80 bbls displaced and saw dart latch wiper plug 90 bbls into displacement. Increased pump rate to 5 bpm-1000 psi and parked string on depth.;With 10 bbls to go reduced rate to 2 bpm-1500 psi and bumped plug/landing collar at 159 bbls into displacement.FCP 1500 psi.SLB increased to and held 4600 psi(3100 over fcp)for 3 minutes.;Bled back 1.5 bbls to truck and floats held.RD SLB hardline. Rig increased to 3300 psi,slacked off from 60K to 15K giving us a good indication hanger was set. Worked string 10'10 15'stroke;Note:added cemnet©.5 ppb;continuously while pumping the job.If we did not reciprocate we had no returns.Pumped a total of 354 bbls with a total of 269 bbls returned.Lost 89 bbls a� throughout the job.CIP at 04:30 on 7-14-15.;PU 5'to clear dogs from hanger top,SO with good indication of shear,PU and had good indication we released liner string.PU,rotated at 10 rpm,SO and set down 65K to set packer.;Top of liner hanger at 6563.39',top of landing collar at 11074.02'.Bled off pressure to 0 psi,then pressured up to 1000 psi and PU 15'.Once psi dropped rig started pumping and did one full circ at;258 gpm-599 psi.With no indication of Mud Push or cement to surface.Closed upper rams,lined up on kill line,pressured up on annulus to 700 psi and held for 10 minutes,good indication;HRD-E ZXPN liner top packer set. Bled off,opened rams and monitored well during crew change.Well is static.;;Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3850 bbls Hauled 220 bbls Class II fluid to GBM,Total Class II fluid hauled=9423 bbls • Hilcorp Energy Company Composite Report Well Name: NINU Blossom 01 Field: Ninilchik County/State: ,AK (LAT/LONG): svation(RKB):18 API#: 50-133-20648-00 Spud Date: 5/24/2015 Job Name: 1413217C Blossom#1 COMPLETION Contractor AFE#: 1413217C AFE$: &ivky Data Ops Summary 7/14/2015 Monitor well 15 minutes during crew change(static)after first clean up circulation.Lay down cement head and 2 singles,pulled liner wiper run tool out of liner hanger.Dropped pipe wiper ball,MU topdrive,up wt 95K.,Pumped one full circulation at 298 gpm-705 psi,up wt 90K,dwn wt 44K while pumping.Again had no indication of mud push or cement to surface.Discussed with Drilling Engineer about testing liner lap to 1,500 psi prior to POOH.,Closed annular,lined up on kill line and DP,pumped down both sides reaching 1,375 psi and hole started taking fluid(3 bbls).Shut down,pressure dropped to 720 psi over 10 minutes indicating liner top packer did not set.Notified Drilling Engineer.Decision made to POOH for dog sub/SBR mill assembly.Bled off well and monitored 30 minutes.Fluid dropped 1.5'over 30 minutes.,POOH from 6,490'to Baker HRD-E run tool.Dog sub was sheared as it should be.Break down and lay down run tool assembly. Offload 18 jots 4-1/2"HWDP from truck.,PU and break down Baker cement head.,Clean rig floor,stage SBR mill assembly,remove upper mill and MU dog sub.,TIH with SBR mill and dog sub assembly on 4-1/2"HWDP from 61'to 556'.,Cont TIH with 4-1/2"DP from 556'to 6,011'.,RIH picking up 16 jts new HWDP making and breaking three times from 6,011'to 6,500'.,CBU at 6 BPM/860 psi with no gas units and no losses.,Pick up additional 4 joints HWDP and tag TOL at 6,563'.Set down 50K and saw good'bobble'indication of dog sub shear.P/U 100 k,S/O 55K.Polish SBR 4 times from 6,563'to 6,583'.15 RPM/6.5-7K torque with 5 BPM/600 psi.Stop rotation and set down 50K once more.,Test liner lap at 1,570 psi on chart for 15 minutes.Bled down to 1,550 psi.Good test.,Flow check well.Static.POOH laying down 20 jts HWDP from 6,618'to 6,011'.,Continue POOH racking back in derrick 6,011'to BHA.,Lay down Baker SBR mill assembly.,Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3,850 bbls. Hauled 180 bbls Class II fluid to G&I,total Class II fluid hauled=9,603 bbls. Daily fluid losses 149 bbls,661 bbls total. 7/15/2015 Pull wear bushing.Rig up to test BOP with 2-7/8".Test annular,upper and lower variable rams at 250 psi low f/5 minutes,4,000 psi high f/10 minute intervals.RD test equipment,install 9"ID wear ring.Stage 2-7/8"handling equipment to rig floor.,Held PJSM with rig crew and Weatherford crew,RU tongs and handling equipment for 2-7/8"string.,PU and MU 3.828"OD multiback casing cleanup tool(Swaco scraper)dressed with a 3.6875"4 blade bit(1"circ port).PU and single in hole with 2-7/8"workstring(2-3/8"SLH 90 threads)to 3,749',drifting joints with 1.90"drift while PU.,Cont to PU and single in hole with 2-7/8"workstring from 3,749'to 4,538'.,R/D Weatherford power tongs. Clear rig floor.,PU and MU#1 6.495"OD multiback casing cleanup tool(Swaco scraper).Continue to RIH with pipe out of derrick from 4,538'to 6,463'.,Circulate bottoms up at 6 BPM/2,150 psi.,Rig up test lines.Test casing at 3,550 psi on chart for 30 minutes.Took 5 bbls to pressure up/bled back 4.8 bbls.Good test.Bleed off and blow down lines.,RIH from 6,463'to 7,803'. PU and MU#2 6.495"OD multiback casing cleanup tool (Swaco scraper).Had no issue entering liner top at 6,563'.,Continue RIH with casing clean out assembly.P/U 142K,S/O 54K. Wash down from 10,895'to cement stringers at 11,030'. Pumping at 5 BPM/3050 psi.Able to slowly wash down to 11,035'. Increased pump rate to 6 BPM/3,300 psi and worked in 7 rounds while working down to 11,038'. Began losing pump pressure to 2,800 psi.Picked up off bottom and lowered pump rate to 2 BPM/1,040 psi.Consulted with drilling engineer.,Hauled 0 bbls cuttings to G&I,Total cuttings hauled=3,850 bbls. Hauled 180 bbls Class II fluid to G&I,total Class II fluid hauled=9,783 bbls. Daily fluid losses 0 bbls,661 bbls total. 7/16/2015 At 11,037',pumped at 2.5 bpm-1,056 psi watching for indication of wash out in drill pipe.Pressure stable at 1,056 psi.Increased pump rate back up to 5 bpm, pressure stable at 2,700 psi.Rack back one stand 4-1/2"DP and reduce topdrive torque to 7,900 ft/lbs.,Latch up stand,MU topdrive and resume circ at 5 bpm- 2,600 to 2,700 psi.Rotate topdrive at 15 to 20 rpm and rotate/wash down tagging cement at 11,037'.Upon tagging cement topdrive stalls.Cont to cycle workstring picking up to breakover point,then slack off and tag cement while rotating.Cont this making 6"each time.Cleanout cement from 11,037'to 11,074'(top of landing collar)with no issues.,Held PJSM with rig crew and Peak crew discussing displacement steps.Start fresh water displacement at 5 bpm-ICP 2,740 psi,FCP 2,415 psi and displaced well to fresh water.Initial up wt with mud in hole 185K,up weight after displacement to water 235K.Pumped a total of 340 bbls water.Broke off topdrive,drill pipe and well are static(not u-tubing).,Pull short trip up hole from 11,074'to 7,806'(52 stands)to upper multiback combo tool(Swaco scraper).Up wt 235K coming off bottom with lots of drag now that well is displaced to water.,TIH from 7,806'to 11,074'(52 stands),down weight at 7,806'=48K,down weight at 11,074'=60K Displace well with 450 bbls fresh water,followed with 25 bbls caustic wash,followed with 25 bbls bara clean pill,followed with 25 bls hi-vis spacer, followed with 407 bbls 3%filtered KCL brine.Pumping at 5 bpm-2,300 psi.NTU's=175 at shut down.Circulated through both rig pumps to flush pumps and lines during fresh water circulations.,POOH from 11,074',lay down 4-1/2"DP.Lay down upper Swaco scraper,cont POOH from 7,820'lay down 4-1/2"DP and HWDP, lay down second Swaco scraper.,Rig up Weatherford power tongs.,POOH,laying down 2-7/8"drill pipe.,Hauled 0 bbls cuttings to G&I,total cuttings hauled= 3,850 bbls. Hauled 1,065 bbls Class II fluid to G&I,total Class II fluid hauled=10,848 bbls. Daily fluid losses 0 bbls,661 bbls total. 7/17/2015 POOH and LD remainder of 2-7/8"workstring from 4,409'.Scrapers and 3.6875"bit in good shape.LD total 146 joints.,Clear rig floor,pull wear ring,C/O 2-7/8" handling equipment to 4-1/2",staged seal assembly and tubing on piperacks.PJSM with rig crew,Weatherford tong hand and Baker Rep.,PU 43'section of 4.74" OD GBH-22 locating seal assembly with 5.69°locator sub.PU and RIH with 4-%"12.6#,L-80 IBT completion tubing to 3,578'.Shipped drill pipe bunks,cement silos and upright water tank to GO pad.Pollard reps on location at 18:00 hrs and installed live valve in chem inj mandrel.,Cont to single in hole with 4-1/2" completion tubing from 3,578'to 4,554'.MU 4-1/2"chemical injection mandrel(OD 6.750"),test control line at 800 psi for 10 minutes.,Cont to single in hole with 4- /2"completion tubing from 4,554'to 6,510'.,Pick up 2 joints and engage no-go in SBR and confirm set down with 5K.Lay down one joint of tubing.Calculate space out.,R/U and reverse 172 bbls of corrosion inhibitor down annulus at 2.8 BPM/70 psi.,Make up pup joint,tubing hanger and landing joint.Terminate control line through tubing hanger and retest at 800 psi/10 minutes. Land string and run in lock down screw.70K P/U,30K S/0. Used 104 SS bands.,Rig up lines and test annulus at 2,160 psi&bled down to 2,020 psi on chart for 30 minutes.Tubing side wide open with no flow back.Good test.,Rig up on tubing and begin testing 4- 1/2"tubing and 4-1/2"liner at 5,000 psi on chart for 30 minutes.,Hauled 0 bbls cuttings to G&I,total cuttings hauled=3,850 bbls. Hauled 520 bbls Class II fluid to G&I,total Class II fluid hauled=11,368 bbls. Daily fluid losses 0 bbls,661 bbls total. 7/18/2015 Cont to pressure up on 4-1/2"completion tubing and 4-1/2"liner,to 5,000 psi and hold for 30 minutes on chart.Gauge on 7-5/8"x 4-1/2"annulus reading 0 psi. Good test.Bleed off tubing and RD test equipment.,RD Weatherford tongs and handling equipment.Release Weatherford.,LD landing joint,Cameron installed BPV.,RD flowline,drip pan and riser.Remove kill and choke lines.Remove Koomey lines.Install trolly beams in cellar.Peak staged two cranes.Welder on location replacing airboot equalizers between pits with hammer seal connections.Shipped DD shack to GO pad,loaded drum products on trailer,loaded mat boards on trailer,loaded and shipped Weatherford tools to town.ND BOP.,NU tree and cap.Pull BPV,install 2 way check.Cameron tested void and tree at 250/5,000 psi.Good test.Bled off and remove 2 way check.Did not re-install BPV.Pits are clean. Rig Released at 18:00 hrs on 7-18-15. 7/29/2015 Held safety meeting with crews and CLU-11. Rigged up N2 pump. Crews departed for Blossom pad.,Crews travel from Cannery Loop to Blossom pad with pump truck.,On location. Obtain PTW and held safety meeting with production lead. Lay pit liner. Spot equipment and return tank. Rig up CTU 12 with 1.75in CT.,Start BOP test. Draw down test. Low pressure test rams and valves to 250/4,500 psi. Witness waived by Jim Regg,AOGCC. Copy of sundry posted in CTU ops cab.,Shut down equipment. Close ground valves and perform walk around of location. Location secure and crews off location. • i 7/30/2015 Hold safety meeting and obtain PTW. Review JSA and discuss job procedures.,Pick injector head. Stab 40 ft of lubricator. Make up CC. Pull test and pressure test. Install disconnect and ported x over to 3/4"sucker rod. Install CBL and CCL tools with memory battey: 33.4 ft of memory tools with coil BHA. Stab on well. Pressure tets lubricator 250/4,500 psi.,RIH. Perform weight checks every 3,000 ft. Slow down at 11K feet. Stop coil at 11,040 ft CTMD. RKB 11,045 ft. 30 ft of bottom. Cannot tag PBTD due to CBL compression limitations of 150 lbs of force. Mechanical counter on reel reads 11,052 ft.,Let tools sit at depth for 3 minutes. Begin POOH at 30 ft/min from 11,040'CTMD to 6,550 ft. Stopped at 6,550 ft and let tools sit for 3 minutes.,RIH at 110 ft/min to 11,040 ft. Let tools sit for 3 minutes. Perform second run for cement bond log.,On depth at 11,040 ft. Begin POOH at 30 ft/min.to 6,550 ft.,Parked at 6,650'. Wait three minutes. RIH at 11,040 ft CTMD. Review and discuss placement of painted flags.,Pick up to 11,000 ft in tension. Set reel brake and injector brake. Paint red flag. POOH at 60 ft/min logging with CCL. Parked at 10,650 ft CTMD. Mechanical counter reads 10,653 ft. Paint white flag. Continue POOH at 60 ft/min to 10,000 ft.,CCL logging interval complete. POOH to surface. At surface. Swab master closed. Breaking off well. Break down tools.,Downloading data from CBL and CCL. Stacking down lubricator. Injector head on deck. Data confirmed. Memory hand said it needs fine tuning before he can tell how well logs will look. Wellsite secure. Crews off location. Will submit data to town as soon as recieved from memory hand. 7/31/2015 Obtain PTW. Hold safety meeting and discuss job steps and procedures. Review Schlumberger JSA.,Pick injector head. Stab 40 ft of lubricator. RIH make up to reverse out nozzle. 3.5"OD nozzle with 5/8"hole and 6 each 1/8"ports. Stab on well. Pressure test lubricator 250 and 4,500 psi.,Open well RIH 0 psi whp (cased hole no perfs),opened choke and took returns from pipe displacement. 10:00 hrs cool down nitrogen.,RIH and cooling down. Online N2 at 5,000 ft down CT annulus taking returns up 1.75in CT string to open top tank. 800 scf/min.,Tag PBTD at 11,053 ft. 60 bbls returned from wellbore. Pick up 5 ft off bottom. Continue to unload wellbore. 132 bbls in open top tank. Calculated well volume would be 168 bbls.,Returns dying down. No N2 at surface or seeing any build up in pressure on CT string. Returns stopped. Investigage surface equipment to determine problem.,Line up fluid,pump down coil to pressure up and attempt to unplug CT. Pumped 4 bbls,didn't see pressure increase. Assumption that reel was full of 25 bbls of fluid incorrect. Decided to pump a full reel volume of 25 bbls down CT string to unplug. 25 bbls away and closed choke,started seeing communication between coil and CT x tubing annulus increasing in pressure together and consistent.,Previous step we picked up 1,000 ft off bottom. 10,000 ft CTMD. Attempt to regain communication with reversing out. Online with N2 down back side. Good returns at tank. 112 bbls in open top tank at returns stopped. No N2 at surface. 25 bbls less than last time at surface.,Decided to attempt N2 lift conventionally down CT. Moved N2 unit to opposite side of equipment and rigged up to pump line. Cooling down N2. Opened annulus up to CT reel to save some nitrogen. Isolated from annulus. Online down CT string at 800 scf/min. Open choke and bleed of 2,300 psi of wellhead pressure from N2. Increase rate to 1,500 scf/min.,Fluid at open top. Estimated at 1.5 bbls/min. RIH to PBTD. Continue blow down well. Return tank blowing dry. Return strap 171 bbls. 3 bbls over calculated volume. Start POOH to surface. Shut in choke and pressure up wellbore. Out of N2. Total N2 pumped 350,000 scf or 3,760 gallons. 171 bbls returned.,POOH 120 ft/min at surface. Ran out of N2 before able to get 2,000 psi on well. Shut in swab with 673 psi. N2 will not arrive until noon following day. Seward Highway closed and Air Liquide transports in Prudhoe Bay.,Pop off well. Stack down lubricator. Set down injector head. Close all ground valves. Location secure. Crews will arrive at 0900 hrs follwing day and make up firing head and presssure test. RIH and get on depth while N2 tanker enroute. 8/1/2015 Obtain permit to work. Hold safety meeting. Review JSA and discuss job procedures.,Pick injector head and 40 ft of lubricator. Make up DFCV,hydraulic disconnect and TCP firing head. Stab on well and pressure test up back side. 250 psi low 3,500 psi high. Good pressure test. Bleed down and pop off well.,Hold safety meeting for making up guns. Make up 15 foot 2.88"6 SPF 60 Deg 2906 PJ Nova HMX 16.9gm guns. Stab on well. Pressure test lubricator 250 (- 1,1•4 psi and 3,500 psi. Good pressure test. Bleed down to 650 psi, Air Liquide nitrogen transport on location.,Open well and RIH. 671 psi on wellhead. (Nitrogen pressure from previous day.) Reviewed memory log EOP calculations sheet. Noticed 7 ft discrepancy. Made calls to engineers in town as well as SLB memory personnel to review and verify correct flag depths. Uncorrected log sent to town looks to be off 7 ft. Continue RIH.,Start cooling down N2 i 10,177 ft. On line with Nitrogen down back side to pressure up well in order to be under balanced when shooting perf guns. Waiting on corrections to be made to logs.,Perf guns past flag. 11,061 ft. Pick up to flag depth and park CT. Well pressured up with N2 to 2,000 psi. SLB memory correcting logs and communicating with town to explain log errors.,New perf depths moved up hole 6 ft due to error in memory log flag depth. Given the go ahead to fire new depths. Flag depth 10,999.80+ 36.1 ft tool reference from CBL+CCL and MHA. No depth offset due input. Perforations depths were shifted vs entering depth offset to put pass on depth. Corrected EOP at flag 10,963.7 FT. End of pipe to bottom shot of 15ft gun 27.34 ft. Bottom shot at flag is 10,991.04'.,POOH from flag 4 ft to position ball drop. Drop 1/2 in aluminum ball in CT spool against inside reel valve. Pressure up to 1,500 and launch ball followed by 3 bbls of 6%KCL and then 1,500 scf of nitrogen. Ball confirmed moving in CT. Increased N2 rate to 2,200 scf/min. Pick up to 10,963'bottom shot. Perf interval 10.971'-10.986', Weight dropped 6,958 lbs guns fired. Down on N2 pump. WHP increase 84 psi.,POOH at surface,guns fired, ball recovered.,1,707 psi SITP. Pressue dropped due to pulling CT OOH. Will see if pressure built up in AM. Stack down injector head. Location secure. Crews off location. 8/2/2015 Obtain PTW. Hold safety meeting and discuss job procedures.,Pick injector head. Stab 40 ft lubricator. Make up CT check valves and disconnect. Install firing head. Stab on well. Pressure test firing head down back side to 250 and 3,500 psi. Bleed down. Pop off well. Install 30 ft gun. 2.88"guns,6SPF,6-deg, 2906 PJ Nova HMX 16.9 gm. .38"ent hole,30.70"penetration. Stab on well. Pressure test 250/3,500 psi. Bleed down to 1,700 psi.,Open well and RIH. 1,688 psi wellhead pressure. No increase throughout the night. (1,709 psi 8-1-15) Run past flag depth. Pick up in tension. Stop at flag 10,650 ft CTMD.,Hold brief safety meeting and discuss good ball drop practices. Input detph in CT counter to ready bottom shot at flag. 10,653.11 ft. Drop ball in CT. Come online for high pressure stall with fluid. Launch ball.25 bbls pumped. Open N2 line with 2,500 psi. Online N2 1,500 scf/min. Down on fluid pump and isolate. Ball audibly moving in CT at surface. Pumping ball to seat.,Pick up to shot depth 10,587.9'CT. CT weight 37,700 lbs. Wellhead N2 pressure 1,991 psi. N2 coil pressure before ball on seat 1,037 psi. Pressure building and shot fired via weight loss to 25,175 lbs and©3,150 psi CT pressure. Offline with N2. Total N2 pumped to shoot interval 30,000 scf or 322 gallons.,Small build up of wellhead pressure due to 3,150 psi shot pressure inside CT. POOH to surface. At surface.,Close master and swab. Bleed down stack. Check no flow. Pop off well. All shots confirmed fired. Guns are dry. Stack down 30 ft gun. 1/2 in ball recovered.,Make up new firing head. Stab on well. Low and high PT firing head to 250/3,500 psi. Good pressure test. Bleed off and pop off well. Make up 25 ft gun. Stab on well. Low PT and high pt 250/3,500 psi. Good pressure test.,Bleed stack to 1,800 psi and open master and swab. 1,724 psi whp. RIH for 3rd gun run. Cool down N2 at 7,400 ft. Wellhead built to 2,061 psi. Bleed down to 1,750 psi through choke.,Stopped at white flag. 10,650 ft. Correct flag depth to 10,653.11 Line up reel for ball drop. 1/2"ball loaded in reel. High gear stall with 6 h KCL 1,475 psi. Open valve. Ball launched. Pump 1/4 bbl. Open N2 line with 3,000 psi. Down on fluid pump. Isolate pump. N2 rate 2,200 scf/min. Pick up to 10,536'with bottom shot.,2.88"guns 6spf,60 deg 2906 PJ Nova HMX 16.9 gm.,CT weight 31,720 lbs. Guns fired at 3,050 psi. Down on N2 pump. CT weight 27,345 lbs. Audible confirmation guns fired. 1,806 psi wellhead pressure after firing. 33 psi increase. Possibly from CT pressure of 3,050 psi. POOH. 31,000 scf pumped to fire guns. (332 gallons) 3,200 gallons remaining from 6,000 ordered.,Continue POOH. At surface. Close master and swab valve. Bleed off to tank. Pop off well. All shots fired. Lay down 25 ft guns. Break off firing head. 1/2in ball recovered. 1,560 psi wellhead pressure when shut in.,Stack down lubricator. Install night cap on BOPs. Injector head on deck. All ground valves closed. Crew picking up tools. Location clean and secure. Crews off location. Company rep and crane operator unloading production water tank from Lynden trailer. • 8/3/2015 Obtain PTW. Hold safety meeting and discuss job procedures with crew. Review SLB JSA.,Pop night cap off BOPs. Pick injector head. Stab 40 ft of lubricator. Make up firing head. Stab on well. 250/3,500 psi pressure test. Bleed down. Pop off well. Install 20 ft 2.88"2906 PJH HMX guns with 6 spf and 60 deg phasing. Schlumberger TCP guns. Stab on well. 250/4,500 psi pressure test.,Open well. RIH. Initial WHP 1,530 psi. No increase from previous day. 3,200 ft. CCAT (coil acquisition software)crashed. Re-establish corns. Continue to RIH. Wellhead pressure increasing while RIH with 1.75 in CT and 2-7/8"perf guns.,Stop at flag. CT depth reads 10,665 ft CTMD. Flag painted at 10,650 ft. CT unit generator died. Primed pump and fired back up. Position reel to load 1/2 in ball. Corrected EOP at flag is 10,614.6 ft. EOP to bottom shot 27.34 ft. Bottom shot at flag 10,641.94 ft. Input depth in CTU EIM to 10,641.94 ft. Launch ball. Online 1,500 scf/min. Pick up to shoot depth 10,457'-10,487'.,Ball fired after 30,000 scf or 322 gallons of N2 pumped. Shot at 3,548 psi CT pressure with 2,196 WHP. Weight dropped from 35k to 27k. Audible confirmation at wellhead. No significant increase in WHP.,RIH with spent gun to circulate N2 and attempt to lift wellbore. 7-8 bbls pumped on shots 1-3. Stack weight on PBTD at 11,030 ft. Mechanical counter on reel 11,081 ft CTMD. 160 bbls in return tank. Pick up off bottom. Clean up weight 36,000 lbs. Clean RIH weight 4,000 lbs. 2,196 psi WHP.,Open choke and flow well to open top tank. Attempting to flow well with 1,500 psi back pressure. Well bleed down from 2,000 psi to 1,300 psi in 12 minutes. Holding 1,300 psi consistently without changing choke beans. N2 cooled down. Online down CT string 1,500 scf/min. Open choke and slowly bleed down to 1,000 psi. N2 circulating pressure 2,450 psi. Continue to work choke open 800 psi.,Once fluid returns hit surface WHP dropped to 500 psi. 8 bbls returned WHP climbing to 1,000 psi. Continue to blow N2. Mostly N2 at return tank. Decided to start POOH.,Attempt to POOH. Pulling 7K over string weight 42K on weight gauge. CT stuck at PBTD or 11,032 ft. Pick up heavy to 11,020 ft. Keep working pipe up and down. No luck freeing CT. Assumptions that CT stuck by friction,differential pressure or fill/debris.,First attempt to check and see if CT is stuck due to fill/debris. Online with 6%KCL at 1.2 bbls/min and 600 scf/min. CT pressure 3,400 psi. Pump 132 bls to gain circulation,still attempting to free string. PU and set down. No luck. 11,032 ft up to 11,020 ft. 42k weight 7k overpull.,Fluid at open top tank. Returns look clean. No solids/sand in samples. Good indication sand/debris was not our problem. Could possibly be differentially stuck. Close choke and offline with N2. Running low on N2. Decided to save remaining 1,000 gallons. Increase fluid rate to 1.5 bbls/min. Close choke and attempt to pressure up wellbore. 1,269 psi on wellhead. Attempt to move pipe up and down. No luck.,Open choke and bleed off 1,269 psi. Continue to circulate. Call town and discuss plan forward. Decision was made to drop disconnect ball. 7/8"ball confirmed with caliper. Line up reel and drop ball. Reel volume is 25 bbls.,Ball launched. Online with 6%KCL at 1.5 bbls/min down CT string. Ball on seat after 22 bbls away. Estimated disconnect pressure 2,900-3,800 psi. CCAt acquisition system locked up. Watching pump pressure gauge at panel. Disconnect shear pressure 4,600 psi. Attempt to PU off fish. No luck 42k weight. RIH and stack weight. Still stuck. 6 attempts made to pull from perf guns.,When picking up weight pressure would drop but weight would still pull heavy. When stacking weight pressure would increase while pumping down CT. Look to still be inside fishing neck.,PU and CT broke free 37,000 weight. After CT broke free didn't see any overpull. Doesnt'appear to be sand/debris. Clean pick up. Start POOH 100 ft/min. Continue to circulate at 1.3 bbls minute until above perforations. Parked at 10,400 ft. Down on fluid pump. Online with N2 at 1,000 scf/min. Attempt to blow well dry with remaining N2. 800 gallons pumped.55 bbls returned prior to loosing N2 prime.,POOH. Returns stopped at surface. 2,300 psi N2 pressure remaining in CT. POOH and swab/create N2 bubble. Additional 58 bbls returned to surface while POOH. 113 bbls totaly at surface. Estimated 60 bbls remaning in wellbore. At surface. N2 bleeding down. Pinching in choke. Fluid returns stopped. Choke closed, 0 psi on wellhead.,At surface. Master and swab closed. Disconnect off wellhead. 20 ft gun still attached to disconnect. All shots fired. Rig down guns. Ball recovered. Break down disconnect and inspect. Disconnect pins sheared all 4 pins. 7/8"ball on seat. Held disconnect in vise and tapped on installed pull plate. Minimal force required to pull bottom sub.,Indicating that CT was not stuck around perforating guns but up hote.,Stack down lubricator. Set injector down. Install night cap 8/4/2015 Obtain PTW. Hold safety meeting and discuss job procedure.Review SLB JSA.,Check well pressure. 70 psi. Sniff with gas detector mostly N2. Pick injector head and stab 10 ft of lubricator. Install coil check valves,disconnect and 2.5in jet swirl nozzle. Zero at bottom of lubricator. Stab on well. Pressure test stack 250/4,500 psi.,Open well and RIH. Slow down for liner top packer. Didn't see any weight bobbles. 113 bbls in return tank. 4,000 ft weight check 7K. Cooling down N2. Online with N2 @ 800 scf/min @ 9,560 ft. 1,300 psi ct pressure.,Increase N2 1,500 scf/min. Blowing well dry. CT @ 10,965 ft. 30K wt check. Fluid returns at surface. Starting strap 113 bbls. Cycle pipe from 10,588'to 10,980'. Up and down. Saw 4-22%LEL prior to lifting fluid to surface.,1,226 psi N2 pressure on CT. 759 psi wellhead. Choke 1/4 open. 70 additional bbls of fluid recovered. Bringing total to 183.4 bbls. 20 bbls added from pump displacement tank used for BOP test. 163 bbls returned from wellbore. POOH 80 ft/min. 10,500'down on N2. Wellhead pressure started dropping. Pinch in choke. Choke closed holding 621 psi. POOH to surface and monitor wellhead.,POOH. Wellhead pressure not increasing. 622 psi. Shut in wellhead. Rig off injector head. Cooling down N2 to perform bullhead job.,Pop off well. Stack down lubricator and cut off coil tools. Set injector head on stand. Install night cap on BOPS. Remove BOPS from well. Install tree cap.. N2 cooled down. Online n2 @ 1500 scf/min. Increase N2 rate to 3200 scf/min. Attempt to build WHP above bottom hold pressure. 1100 gallons of N2 pumped for bull head job. Steady pressure increase.,No breakover when pressuring up well. Lost prime on n2 pump. 2560 psi. Monitor pressure. No increase or decrease. Production personnel on location to flow well. SLB start rigging down.,Called out 6000 more gallons of N2. Air liquid estimated to arrive 0800 following morning. Crews rigged down. Location secure. NO gas seen at surface. PRessure bleed down to 500 psi and then shut in. Will perform another attempt at N2 bullhead tomorrow. 8/24/2015 PTW and JSA.Spot and rig up equipment.Test Weltec tractor and PDS caliper.Rig up lubricator,pressure test to 250 psi low and 3,500 psi high. TP-1,250 psi.,RIH with Weltec tractor and PDS caliper.Run tractor from 1,742'to 5,315'.RIH and start having problems with dried drilling mud that is on wireline due to using the unit for Blossom stuck pipe job a while back starting at 7,826'.Cleaned line as it went down to 9,980'.Line torqued up and spun the top shelve.That kinked the line so it would not run thru grease tubes.Got line straightend out and POOH.,Rig down lubricator and tools.Get ready to bring another truck in morning and cont with job. 8/25/2015 PTW and JSA. Rig up lubricator put tractor and caliper online and test.Pressure test to 250 psi and 3,500 psi. TP 1,250 psi.,RIH w/Weltec tractor and PDS caliper and tie into SLB CBL dated 30 Jul 2015.Start tractor at 1,798'and turn off at 5,315'.Run caliper log from 11,020'to 10,150'to cover two RA tags.Send log to town.POOH.,Wait on Pollard GPT tool.RIH w/Weltec tractor,GPT tool,2-7/8"x 15'Connex HC,6 spf,60 deg phase and tie into SLB CBL log.Turn tractor on at 3,280'(a lot deeper than before)and off at 5,130'. Found fluid level at 7,080'.Run correlation log and send to town.Get ok to perf and bleed well down from 2,840 BHP to 2,000 psi BHP.Bleed well to 2,000 psi BHP and surface pressure was 499 psi.,Fired gun and saw no pressure increase.Pulling out of hole found FL at 7,020'. Got out of hole and found gun did not fire.,Rig down lubricator for standby. Pollard has trouble shooting problem and will try again tomorrow. 8/27/2015 PTW and JSA. Rig up lubricator,put tractor on line and test.MU pert gun and put on line.Pressure test to 250 psi and 3,500 psi. TP 550 psi.,RIH w/Weltec tractor,2-7/8"x 30'Connex HC,6 spf,60 deg phase and tie into SLB CBL log.Turn tractor on at 3,970'(a lot deeper than before)and off at 5,100'. Run correlation log and send to town.Get ok to perf from 10,582'to 10,612'.TP-550 psi.Fired gun and saw no pressure increase.Lost power to CCUGR after firing shot.POOH.All shots fired.,Rig down lubricator and tools.Turn well over to field.TP-550 psi. Moving equipment to GO-08.Field will be blowing well down checking for gas. 8/31/2015 Obtain PTW. Hold safety meeting and discuss job procedures and associated hazards.,Air Liquide truck not on location. Made calls to Air Liquide distribution manager and SLB management. Rig up N2 pump and iron. Install integral flange on tree.,Air Liquide transport on location. Transfer N2 to pump and SLB n transport. Pressure test N2 lines to 250 low and 5,000 psi high. Good test.,Open well. WHP 126 psi. Bring N2 rate up to 3,000 scf/min. Record pressure in CT 1' ops cab every 5 minutes. Pressure breakover at 3,033 psi. Flat line pressure 2,754 psi.,Increase N2 rate to 4,500 scf/min. 2,948 psi. Pressure increased to 3,648 psi. Break over. Injecting at 3,600 psi.,Increase N2 rate to 5,300 scf/min. 3,612 psi. No major increase in WHP. Injecting 3,634 psi.,Down on nitrogen. �i SITP 3,500 psi. N2 crew and unit standing by to PT CIBP. Total SCF pumped 475,000 or 5,100 gallons.PTW and JSA.Rig up E-line lubricator,PT to 250 psi N$" low and 3,500 psi high RIH with tractor.3.50"CIBP and tie into SLB CBL loq.Turn tractor on at 1,717'and turn off at 5,670'.Run correlation log and send to town. I Get ok to set plug at 10,485'.Pressure tubing up to 3,500 psi with N2.Set plug and lost 200 lbs of line wt.Pick up 30'and go back down and tag plug.POOH.,Rig down lubricator.Pressure tubing up to 4,050 psi and close master valve.Rig down N2. 9/1/2015 PTW and JSA.Rig up lubricator,PT to 250 psi low and 3,900 psi high.Well had 3,915 psi on tubing this am.Plug held.,RIH with 2-7/8"x 20'(loaded with 16' perfs)and 4 roller boogies.Bled well down to 2,030 psi.Started working tools down at 1,800'.Made 500'from 3,200'to 3,700'at one time.Quit at 4,536'and pull out of hole to pick up tractor.Pretty much dead stop at this depth.POOH.,Put tractor on line and test.RIH with 2-7/8'x 20'(loaded with 16'perfs)and tie into Pollard pert log.Turn tractor on at 1,890'and off at 5,500'. Bleed well to 1,520 psi.Tag plug at 10,485',run correlation log and send town. Get ok to pert from 10,324'to 10,340'(per phone conversation with Jeremy).Fired gun with 1,524.5 psi on tubing.After 5 min it was 1,528 psi.Out of hole it was 1,527.5 psi.Gun was dry.,Rig down lubricator and turn well over to field. • • 9/2/2015 PTW and JSA.Rig up SLB pump truck.PT lines to 5,000 psi.Pressure up tubing from 540 psi to 1,500 psi with N2.,PTW and JSA.Rig up E-line lubricator and pressure test with N2 250 psi low and 3,500 psi high.Release SLB N2 crew.Put tractor on line,perf gun and test.,RIH w/Weltec tractor,2-7/8"x 30'Connex HC, 6 spf,60 deg phase and tie into SLB Memory Log.Turn tractor on at 1,770'and off at 5,500'.Run correlation log and send to town.Get ok to pert from 9,900'to 9,930'.Spot shot.TP-1,479 psi.Fired gun and after 5 min tubing pressure was 1,480 psi.POOH. As Pollard was bumping tool up in lubricator they pulled out of the rope socket and dropped tools in hole.,Tubing pressure is 1,477 psi.I have slickline and a different crane lined up to be here in the morning to fish tools out of hole.Rigged lubricator and crane down. 9/3/2015 PTW and JSA.Rig up slickline.Pressure test lubricator to 250 psi low and 3,500 psi high.Dump 28 gals of diesel down hole to cut e-line grease and slick tubing wall up.TP-1509 psi.,RIH with roller boogies and 1-11/16"grapple with 3.75"guide. Worked tools from 1,500'to 1,700'.Pumped 30 more gals of diesel and latched fish at 1,850'WLM.Hand spanged grapple over fish.POOH.Got all tools out of hole.Gun had fired.,Rig up E-line lubricator.Build new rope socket with pull out of 2,700 lbs.Test tractor and make up pert gun.,RIH w/Weltec tractor,2-7/8"x 30'Connex HC,6 spf,60 deg phase and tie into SLB Memory Log.Turn tractor on at 1,860'and off at 5,500'.Run correlation log and send to town.Get ok to pert from 8,844'to 8,874'(T3 Sand).Spot shot.TP-1,534.5 psi.Fired gun, after 5 min tubing pressure was 1,536.5 psi and after 10 min still 1,536.5 psi.POOH.All shots fired.Gun was wet.TP-1,528 psi,Rig down lubricator and secure well. 9/4/2015 PTW and JSA.Rig up lubricator,PT to 250 psi low and 3,500 psi high.Well had 1,575 psi on tubing this am.,RIH w/Weltec tractor,2-7/8"x 20'Connex HC,6 spf, 60 deg phase and tie into SLB Memory Log.Turn tractor on at 1,900'and off at 5,500'.Run correlation log and send to town.Get ok to pert from 8,345'to 8,365' (B134 Sand).Spot shot.TP-1,569 psi.Fired gun and after 5 min tubing pressure was 1,572 psi. POOH. All shots fired.TP is 1,561 psi and gun was wet.,Rig down lubricator,clean up work area and turn well over to field. - 10/19/2015 PTW and JSA.Spot equipment and rig up lubricator.Make up Welltec tractor and 2-7/8"x 16'Connex HC,6 spf,60 deg phase pert gun.Attempt to PT lubricator. Could not get tri-plex to pump fluid.,Add 110 gals methanol and attempt to pump.Would not pressure up.Call for Pollard test pump to mobe and head to location. Started trouble shooting Hilcorp test pump and found the following.Needle valve on the return line was washed out.Replace needle valve and still could not pressure up.Found the Y-block screen on the tank line was scaled up not allowing very little fluid to reach the pump.,Tad did a great job at trouble shooting the pump. Cleaned scale from Y-block and pressure tested lubricator 250 psi low to 3,500 psi high.,RIH with Welltec tractor and 2-7/8"x 16'Connex HC,6 spf,60 deg phase and tie into Pollard correlation gun run#1A dated 8-27-15.Turn tractor on at 1,910'to 2050'.RIH without tractor to 2,900'.Tractor to 5,700'.Turn off tractor at that depth. Run correlation log and send to town.Get ok to pert from 10,392'to 10,408'.Fired shot with 683.7 psi on tubing.After 5 min TP was 682.5 psi.POOH and all shots fired.,TP was 662 psi.Decided to do last gun run in the morning since it would be 2-4 am in the morning by the time job was done and rigged down.Tagged plug at 10,481'.,Rigged for standby.Got tools ready to start first thing in the morning.Left crystal gauge recording on well. 10/20/2015 PTW and JSA.Rig up lubricator,PT to 250 psi low and 3,500 psi high.TP-671.5 psi.,RIH w/2-7/8"x 8'HC,6 spf,60 deg pert gun and Welltec tractor.Start tractor at 1,910'and turn off at 5,700'.Ran correlation log gun 2 dated Tue,Oct 20(10:36:27)2015 and send to town.Got ok(Dave Buthman)to perforate from bbb 9 438'to 9 444'(9 440'to 9 448'OH Inn)off this Iryt.Fired gun with 642.3 psi on tubing and after 5 min TP was 641.6 psi.POOH.Gun had fired.,Rig down lubricator and turn well back over to field. • • Hilcorp Energy Company Ninilchik Unit Blossom Rig: Blossom #1 50-133-20648-00-00 50-133-20648-00-00 Sperry Drilling Definitive Survey Report 16 July, 2015 iimmwmumnummo HALLIBURTON pt rry Drilling • • . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Blossom#1 Project: Ninilchik Unit TVD Reference: Actual:Blossom#1 @ 233.20usft Site: Blossom MD Reference: Actual:Blossom#1 @ 233.20usft Well: Blossom#1 North Reference: True Wellbore: Rig:Blossom#1 Survey Calculation Method: Minimum Curvature Design: Blossom#1 Database: Sperry EDM-NORTH US+CANADA Project Ninilchik 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 Using geodetic scale factor Well Blossom#1 Well Position +N/-S 0.00 usft Northing: 2,258,238.57 usfl " Latitude: 60°10'23.684 N +E/-W 0.00 usft Easting: 231,709.77 usfl - Longitude: 151°28'24.180 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 215.20usft Wellbore Rig:Blossom#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 5/5/2015 16.46 73.18 55,197 Design Blossom#1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,470.82 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 332.86 Survey Program Date 7/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 137.96 2,423.71 Blossom#1 PB1 MWD 1 (Blossom#1 PB MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 05/01/2015 2,488.40 6,748.34 Blossom#1 PB1 MWD 2(Blossom#1 PB MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 06/29/2015 6,827.19 7,470.82 Blossom#1 PB1 MWD 3(Blossom#1 PB MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 06/29/2015 7,504.07 11,166.86 Blossom#1 MWD 4(Rig:Blossom#1) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 06/29/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (usfl) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -215.20 0.00 0.00 2,258,238.57 231,709.77 0.00 0.00 UNDEFINED 137.96 0.47 356.49 137.96 -95.24 0.49 -0.03 2,258,239.06 231,709.75 0.39 0.45 MWD+SC+sag(1) 193.23 0.62 356.49 193.23 -39.97 1.02 -0.06 2,258,239.59 231,709.73 0.27 0.93 MWD+SC+sag(1) 260.25 3.65 331.63 260.19 26.99 3.26 -1.10 2,258,241.85 231,708.74 4.62 3.40 MWD+SC+sag(1) 322.23 6.22 329.91 321.94 88.74 7.90 -3.72 2,258,246.55 231,706.23 4.15 8.72 MWD+SC+sag(1) 383.82 9.01 330.69 382.98 149.78 14.99 -7.75 2,258,253.73 231,702.35 4.53 16.88 MWD+SC+sag(1) 444.21 11.76 329.46 442.37 209.17 24.42 -13.20 2,258,263.27 231,697.12 4.57 27.75 MWD+SC+sag(1) 504.64 14.32 329.44 501.24 268.04 36.16 -20.13 2,258,275.17 231,690.45 4.24 41.36 MWD+SC+sag(1) 568.32 17.28 330.08 562.51 329.31 51.14 -28.85 2,258,290.34 231,682.07 4.66 58.67 MWD+SC+sag(1) 629.58 19.73 329.56 620.60 387.40 67.94 -38.63 2,258,307.36 231,672.67 4.01 78.08 MWD+SC+sag(1) 691.16 22.53 328.92 678.03 444.83 87.01 -49.99 2,258,326.67 231,661.74 4.56 100.23 MWD+SC+sag(1) 7/16/2015 6:42:37PM Page 2 COMPASS 5000.1 Build 73 • . . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Blossom#1 Project: Ninilchik Unit TVD Reference: Actual:Blossom#1 @ 233.20usft Site: Blossom MD Reference: Actual:Blossom#1 @ 233.20usft Well: Blossom#1 North Reference: True Wellbore: Rig:Blossom#1 Survey Calculation Method: Minimum Curvature Design: Blossom#1 Database: Sperry EDM-NORTH US+CANADA 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) (0/100') (ft) Survey Tool Name 753.82 25.09 329.46 735.35 502.15 108.74 -62.94 2,258,348.68 231,649.27 4.10 125.48 MWD+SC+sag(1) 814.96 27.38 329.23 790.19 556.99 131.99 -76.72 2,258,372.23 231,636.02 3.75 152.45 MWD+SC+sag(1) 877.06 30.23 329.97 844.60 611.40 157.80 -91.85 2,258,398.37 231,621.46 4.63 182.32 MWD+SC+sag(1) 938.85 33.44 330.69 897.09 663.89 186.12 -107.97 2,258,427.05 231,605.98 5.23 214.88 MWD+SC+sag(1) 1,000.99 36.39 330.78 948.04 714.84 217.14 -125.36 2,258,458.45 231,589.29 4.75 250.42 MWD+SC+sag(1) 1,063.70 39.18 331.38 997.59 764.39 250.77 -143.93 2,258,492.48 231,571.47 4.49 288.82 MWD+SC+sag(1) 1,124.86 42.16 329.96 1,043.98 810.78 285.51 -163.47 2,258,527.65 231,552.72 5.10 328.64 MWD+SC+sag(1) 1,186.33 45.05 329.56 1,088.49 855.29 322.13 -184.82 2,258,564.73 231,532.19 4.72 370.97 MWD+SC+sag(1) 1,249.03 48.08 330.44 1,131.59 898.39 361.56 -207.57 2,258,604.66 231,510.32 4.94 416.43 MWD+SC+sag(1) 1,311.55 50.29 329.26 1,172.45 939.25 402.46 -231.34 2,258,646.09 231,487.47 3.81 463.68 MWD+SC+sag(1) 1,373.34 52.53 328.92 1,210.99 977.79 443.90 -256.15 2,258,688.06 231,463.59 3.65 511.87 MWD+SC+sag(1) 1,434.45 54.15 329.45 1,247.48 1,014.28 486.00 -281.26 2,258,730.71 231,439.43 2.74 560.79 MWD+SC+sag(1) 1,495.98 57.11 329.38 1,282.21 1,049.01 529.71 -307.10 2,258,774.99 231,414.57 4.81 611.48 MWD+SC+sag(1) 1,558.19 61.14 329.70 1,314.13 1,080.93 575.73 -334.16 2,258,821.60 231,388.54 6.49 664.77 MWD+SC+sag(1) 1,620.81 63.35 329.98 1,343.29 1,110.09 623.64 -362.00 2,258,870.12 231,361.78 3.55 720.11 MWD+SC+sag(1) 1,681.65 67.29 330.96 1,368.68 1,135.48 671.74 -389.23 2,258,918.81 231,335.63 6.64 775.33 MWD+SC+sag(1) 1,743.66 71.15 331.97 1,390.68 1,157.48 722.66 -416.92 2,258,970.34 231,309.09 6.41 833.28 MWD+SC+sag(1) 1,805.85 74.49 332.18 1,409.05 1,175.85 775.15 -444.74 2,259,023.44 231,282.44 5.38 892.68 MWD+SC+sag(1) 1,868.60 75.97 331.80 1,425.04 1,191.84 828.72 -473.23 2,259,077.63 231,255.15 2.43 953.35 MWD+SC+sag(1) 1,930.01 77.16 331.61 1,439.31 1,206.11 881.31 -501.54 2,259,130.84 231,228.02 1.96 1,013.06 MWD+SC+sag(1) 1,990.97 76.62 332.10 1,453.14 1,219.94 933.66 -529.55 2,259,183.80 231,201.19 1.18 1,072.42 MWD+SC+sag(1) 2,054.34 74.47 332.56 1,468.96 1,235.76 988.00 -558.05 2,259,238.76 231,173.91 3.46 1,133.78 MWD+SC+sag(1) 2,116.65 73.19 332.71 1,486.31 1,253.11 1,041.15 -585.55 2,259,292.51 231,147.60 2.07 1,193.62 MWD+SC+sag(1) 2,178.22 73.53 330.07 1,503.94 1,270.74 1,092.93 -613.80 2,259,344.91 231,120.52 4.15 1,252.59 MWD+SC+sag(1) 2,240.18 73.88 329.53 1,521.33 1,288.13 1,144.33 -643.71 2,259,396.96 231,091.76 1.01 1,311.98 MWD+SC+sag(1) 2,301.32 75.98 329.08 1,537.22 1,304.02 1,195.10 -673.85 2,259,448.38 231,062.76 3.51 1,370.90 MWD+SC+sag(1) 2,363.14 76.12 329.37 1,552.13 1,318.93 1,246.64 -704.55 2,259,500.60 231,033.22 0.51 1,430.77 MWD+SC+sag(1) 2,423.71 74.98 329.94 1,567.24 1,334.04 1,297.26 -734.18 2,259,551.86 231,004.73 2.09 1,489.33 MWD+SC+sag(1) 2,488.40 75.15 330.52 1,583.91 1,350.71 1,351.52 -765.22 2,259,606.80 230,974.91 0.91 1,551.77 MWD+SC+sag(2) 2,495.00 75.03 330.58 1,585.61 1,352.41 1,357.07 -768.35 2,259,612.42 230,971.90 1.95 1,558.14 MWD+SC+sag(2) 10 3/4" 2,550.18 74.07 331.07 1,600.31 1,367.11 1,403.51 -794.28 2,259,659.42 230,947.01 1.95 1,611.30 MWD+SC+sag(2) 2,610.36 73.37 330.84 1,617.18 1,383.98 1,454.01 -822.32 2,259,710.54 230,920.10 1.22 1,669.03 MWD+SC+sag(2) 2,674.52 72.47 331.45 1,636.02 1,402.82 1,507.72 -851.92 2,259,764.90 230,891.71 1.67 1,730.33 MWD+SC+sag(2) 2,736.22 72.98 331.39 1,654.35 1,421.15 1,559.46 -880.11 2,259,817.25 230,864.69 0.83 1,789.23 MWD+SC+sag(2) 2,795.57 73.54 330.36 1,671.44 1,438.24 1,609.11 -907.77 2,259,867.50 230,838.14 1.91 1,846.03 MWD+SC+sag(2) 2,857.65 72.74 331.45 1,689.45 1,456.25 1,661.02 -936.66 2,259,920.04 230,810.42 2.12 1,905.41 MWD+SC+sag(2) 2,919.60 75.99 329.44 1,706.14 1,472.94 1,712.90 -966.09 2,259,972.57 230,782.15 6.11 1,965.00 MWD+SC+sag(2) 2,981.31 76.37 329.17 1,720.88 1,487.68 1,764.43 -996.68 2,260,024.76 230,752.72 0.75 2,024.81 MWD+SC+sag(2) 3,043.14 77.20 329.36 1,735.02 1,501.82 1,816.17 -1,027.44 2,260,077.17 230,723.12 1.38 2,084.88 MWD+SC+sag(2) 7/16/2015 6:42:37PM Page 3 COMPASS 5000.1 Build 73 i i Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Blossom#1 Project: Ninilchik Unit TVD Reference: Actual:Blossom#1 @ 233.20usft Site: Blossom MD Reference: Actual:Blossom#1 @ 233.20usft Well: Blossom#1 North Reference: True Wellbore: Rig:Blossom#1 Survey Calculation Method: Minimum Curvature Design: Blossom#1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,105.40 76.17 329.33 1,749.36 1,516.16 1,868.29 -1,058.33 2,260,129.97 230,693.40 1.66 2,145.35 MWD+SC+sag(2) 3,168.37 76.94 329.55 1,764.00 1,530.80 1,921.02 -1,089.47 2,260,183.39 230,663.45 1.27 2,206.49 MWD+SC+sag(2) 3,229.29 76.88 329.78 1,777.79 1,544.59 1,972.24 -1,119.44 2,260,235.25 230,634.63 0.38 2,265.73 MWD+SC+sag(2) 3,291.55 77.19 329.41 1,791.76 1,558.56 2,024.56 -1,150.14 2,260,288.25 230,605.10 0.76 2,326.31 MWD+SC+sag(2) 3,353.80 77.63 329.46 1,805.33 1,572.13 2,076.88 -1,181.04 2,260,341.24 230,575.38 0.71 2,386.95 MWD+SC+sag(2) 3,415.63 76.10 329.75 1,819.38 1,586.18 2,128.81 -1,211.50 2,260,393.84 230,546.08 2.52 2,447.06 MWD+SC+sag(2) 3,478.20 76.23 329.47 1,834.34 1,601.14 2,181.22 -1,242.24 2,260,446.92 230,516.52 0.48 2,507.72 MWD+SC+sag(2) 3,537.60 76.00 329.59 1,848.60 1,615.40 2,230.92 -1,271.48 2,260,497.26 230,488.40 0.43 2,565.29 MWD+SC+sag(2) 3,601.71 75.41 329.04 1,864.43 1,631.23 2,284.35 -1,303.18 2,260,551.38 230,457.90 1.24 2,627.29 MWD+SC+sag(2) 3,663.09 76.25 328.34 1,879.45 1,646.25 2,335.19 -1,334.11 2,260,602.90 230,428.11 1.76 2,686.65 MWD+SC+sag(2) 3,725.67 76.43 329.07 1,894.23 1,661.03 2,387.15 -1,365.69 2,260,655.55 230,397.69 1.17 2,747.30 MWD+SC+sag(2) 3,786.41 77.36 329.38 1,908.00 1,674.80 2,437.98 -1,395.96 2,260,707.04 230,368.57 1.61 2,806.33 MWD+SC+sag(2) 3,849.33 77.38 330.01 1,921.76 1,688.56 2,490.99 -1,426.94 2,260,760.72 230,338.78 0.98 2,867.64 MWD+SC+sag(2) 3,911.09 76.57 329.17 1,935.68 1,702.48 2,542.88 -1,457.40 2,260,813.28 230,309.49 1.86 2,927.71 MWD+SC+sag(2) 3,973.03 77.19 330.13 1,949.74 1,716.54 2,594.93 -1,487.88 2,260,866.00 230,280.18 1.81 2,987.94 MWD+SC+sag(2) 4,035.23 77.49 331.19 1,963.37 1,730.17 2,647.84 -1,517.62 2,260,919.56 230,251.63 1.73 3,048.58 MWD+SC+sag(2) 4,097.74 75.41 331.04 1,978.02 1,744.82 2,701.04 -1,546.97 2,260,973.40 230,223.47 3.34 3,109.32 MWD+SC+sag(2) 4,159.36 75.98 330.76 1,993.24 1,760.04 2,753.22 -1,576.01 2,261,026.21 230,195.60 1.02 3,168.99 MWD+SC+sag(2) 4,221.78 76.61 330.86 2,008.03 1,774.83 2,806.16 -1,605.58 2,261,079.80 230,167.22 1.02 3,229.60 MWD+SC+sag(2) 4,283.52 76.43 330.57 2,022.42 1,789.22 2,858.52 -1,634.95 2,261,132.80 230,139.02 0.54 3,289.59 MWD+SC+sag(2) 4,345.49 76.44 329.74 2,036.96 1,803.76 2,910.77 -1,664.93 2,261,185.71 230,110.22 1.30 3,349.77 MWD+SC+sag(2) 4,407.48 75.84 330.18 2,051.81 1,818.61 2,962.87 -1,695.06 2,261,238.47 230,081.26 1.19 3,409.87 MWD+SC+sag(2) 4,468.53 75.76 330.09 2,066.79 1,833.59 3,014.20 -1,724.53 2,261,290.44 230,052.94 0.19 3,468.99 MWD+SC+sag(2) 4,530.89 76.66 330.31 2,081.65 1,848.45 3,066.75 -1,754.63 2,261,343.65 230,024.03 1.48 3,529.49 MWD+SC+sag(2) 4,592.56 76.88 329.91 2,095.76 1,862.56 3,118.80 -1,784.54 2,261,396.35 229,995.28 0.73 3,589.45 MWD+SC+sag(2) 4,654.67 76.51 330.30 2,110.06 1,876.86 3,171.20 -1,814.67 2,261,449.41 229,966.33 0.85 3,649.83 MWD+SC+sag(2) 4,716.73 77.58 329.62 2,123.97 1,890.77 3,223.56 -1,844.95 2,261,502.42 229,937.23 2.03 3,710.23 MWD+SC+sag(2) 4,779.45 77.45 330.15 2,137.53 1,904.33 3,276.53 -1,875.67 2,261,556.07 229,907.69 0.85 3,771.38 MWD+SC+sag(2) 4,840.09 76.57 330.45 2,151.16 1,917.96 3,327.85 -1,904.95 2,261,608.03 229,879.57 1.53 3,830.41 MWD+SC+sag(2) 4,902.91 77.26 329.78 2,165.38 1,932.18 3,380.90 -1,935.44 2,261,661.75 229,850.27 1.51 3,891.53 MWD+SC+sag(2) 4,964.88 77.18 329.57 2,179.09 1,945.89 3,433.07 -1,965.95 2,261,714.58 229,820.93 0.35 3,951.87 MWD+SC+sag(2) 5,026.85 76.75 329.82 2,193.07 1,959.87 3,485.19 -1,996.41 2,261,767.37 229,791.64 0.80 4,012.15 MWD+SC+sag(2) 5,089.13 76.42 329.51 2,207.52 1,974.32 3,537.48 -2,027.01 2,261,820.32 229,762.22 0.72 4,072.64 MWD+SC+sag(2) 5,150.87 74.14 331.37 2,223.21 1,990.01 3,589.41 -2,056.47 2,261,872.90 229,733.92 4.70 4,132.29 MWD+SC+sag(2) 5,211.25 72.34 332.56 2,240.62 2,007.42 3,640.44 -2,083.64 2,261,924.52 229,707.89 3.53 4,190.09 MWD+SC+sag(2) 5,273.84 70.00 333.06 2,260.82 2,027.62 3,693.13 -2,110.71 2,261,977.80 229,682.01 3.81 4,249.33 MWD+SC+sag(2) 5,336.37 66.55 333.53 2,283.96 2,050.76 3,745.01 -2,136.82 2,262,030.25 229,657.07 5.56 4,307.41 MWD+SC+sag(2) 5,397.51 64.22 333.93 2,309.42 2,076.22 3,794.85 -2,161.42 2,262,080.62 229,633.59 3.86 4,362.98 MWD+SC+sag(2) 5,459.54 60.93 334.98 2,337.99 2,104.79 3,844.51 -2,185.16 2,262,130.81 229,610.95 5.51 4,418.01 MWD+SC+sag(2) 5,521.73 58.01 335.98 2,369.58 2,136.38 3,893.24 -2,207.40 2,262,180.02 229,589.81 4.90 4,471.52 MWD+SC+sag(2) 7/16/2015 6:42:37PM Page 4 COMPASS 5000.1 Build 73 • . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Blossom#1 Project: Ninilchik Unit TVD Reference: Actual:Blossom#1 @ 233.20usft Site: Blossom MD Reference: Actual:Blossom#1 @ 233.20usft Well: Blossom#1 North Reference: True Wellbore: Rig:Blossom#1 Survey Calculation Method: Minimum Curvature Design: Blossom#1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (11001 (ft) Survey Tool Name 5,583.84 55.06 336.28 2,403.82 2,170.62 3,940.62 -2,228.37 2,262,227.85 229,569.91 4.77 4,523.24 MWD+SC+sag(2) 5,646.10 51.99 335.76 2,440.83 2,207.63 3,986.36 -2,248.71 2,262,274.03 229,550.59 4.98 4,573.22 MWD+SC+sag(2) 5,707.72 49.10 335.36 2,479.99 2,246.79 4,029.67 -2,268.39 2,262,317.77 229,531.89 4.72 4,620.74 MWD+SC+sag(2) 5,769.13 46.80 335.29 2,521.11 2,287.91 4,071.10 -2,287.42 2,262,359.62 229,513.78 3.75 4,666.30 MWD+SC+sag(2) 5,832.11 44.04 336.19 2,565.32 2,332.12 4,111.99 -2,305.86 2,262,400.90 229,496.26 4.50 4,711.09 MWD+SC+sag(2) 5,893.66 41.60 336.98 2,610.46 2,377.26 4,150.38 -2,322.49 2,262,439.65 229,480.49 4.06 4,752.84 MWD+SC+sag(2) 5,954.93 38.68 336.99 2,657.29 2,424.09 4,186.73 -2,337.93 2,262,476.33 229,465.87 4.77 4,792.23 MWD+SC+sag(2) 6,016.03 36.18 336.04 2,705.81 2,472.61 4,220.79 -2,352.72 2,262,510.72 229,451.84 4.20 4,829.29 MWD+SC+sag(2) 6,078.10 34.39 334.81 2,756.48 2,523.28 4,253.39 -2,367.62 2,262,543.65 229,437.67 3.10 4,865.10 MWD+SC+sag(2) 6,140.90 31.27 336.00 2,809.24 2,576.04 4,284.34 -2,381.80 2,262,574.90 229,424.18 5.07 4,899.11 MWD+SC+sag(2) 6,202.47 28.79 336.59 2,862.54 2,629.34 4,312.55 -2,394.19 2,262,603.38 229,412.42 4.06 4,929.86 MWD+SC+sag(2) 6,264.19 25.13 336.12 2,917.54 2,684.34 4,338.18 -2,405.41 2,262,629.25 229,401.78 5.94 4,957.79 MWD+SC+sag(2) 6,327.13 21.92 336.33 2,975.24 2,742.04 4,361.17 -2,415.54 2,262,652.46 229,392.17 5.10 4,982.86 MWD+SC+sag(2) 6,388.54 19.62 335.06 3,032.66 2,799.46 4,381.02 -2,424.49 2,262,672.50 229,383.66 3.82 5,004.61 MWD+SC+sag(2) 6,451.05 19.95 335.28 3,091.48 2,858.28 4,400.22 -2,433.37 2,262,691.90 229,375.21 0.54 5,025.75 MWD+SC+sag(2) 6,513.77 19.66 335.22 3,150.49 2,917.29 4,419.52 -2,442.27 2,262,711.39 229,366.75 0.46 5,046.99 MWD+SC+sag(2) 6,576.51 19.58 335.75 3,209.59 2,976.39 4,438.68 -2,451.01 2,262,730.75 229,358.43 0.31 5,068.03 MWD+SC+sag(2) 6,638.20 19.51 335.77 3,267.72 3,034.52 4,457.50 -2,459.48 2,262,749.75 229,350.38 0.11 5,088.64 MWD+SC+sag(2) 6,700.75 19.46 336.00 3,326.69 3,093.49 4,476.55 -2,468.01 2,262,768.98 229,342.29 0.15 5,109.48 MWD+SC+sag(2) 6,748.34 19.33 336.25 3,371.58 3,138.38 4,491.00 -2,474.41 2,262,783.57 229,336.21 0.32 5,125.25 MWD+SC+sag(2) 6,785.00 19.34 336.86 3,406.17 3,172.97 4,502.13 -2,479.23 2,262,794.81 229,331.63 0.55 5,137.37 MWD+SC+sag(3) 7 5/8" 6,827.19 19.35 337.57 3,445.98 3,212.78 4,515.02 -2,484.65 2,262,807.81 229,326.51 0.55 5,151.30 MWD+SC+sag(3) 6,890.71 20.22 337.97 3,505.75 3,272.55 4,534.92 -2,492.78 2,262,827.89 229,318.83 1.39 5,172.72 MWD+SC+sag(3) 6,957.84 20.64 339.17 3,568.66 3,335.46 4,556.73 -2,501.34 2,262,849.89 229,310.76 0.88 5,196.04 MWD+SC+sag(3) 7,019.51 19.74 339.02 3,626.54 3,393.34 4,576.62 -2,508.93 2,262,869.94 229,303.61 1.46 5,217.20 MWD+SC+sag(3) 7,085.81 20.23 339.14 3,688.85 3,455.65 4,597.78 -2,517.02 2,262,891.28 229,295.99 0.74 5,239.72 MWD+SC+sag(3) 7,147.01 19.20 339.46 3,746.46 3,513.26 4,617.09 -2,524.32 2,262,910.75 229,289.12 1.69 5,260.24 MWD+SC+sag(3) 7,214.06 19.98 339.92 3,809.63 3,576.43 4,638.18 -2,532.12 2,262,932.00 229,281.80 1.19 5,282.56 MWD+SC+sag(3) 7,276.39 18.61 339.54 3,868.45 3,635.25 4,657.50 -2,539.25 2,262,951.47 229,275.10 2.21 5,303.00 MWD+SC+sag(3) 7,342.39 19.06 339.77 3,930.92 3,697.72 4,677.48 -2,546.66 2,262,971.61 229,268.14 0.69 5,324.16 MWD+SC+sag(3) 7,404.18 19.55 340.25 3,989.23 3,756.03 4,696.67 -2,553.64 2,262,990.96 229,261.58 0.83 5,344.43 MWD+SC+sag(3) 7,470.82 18.38 336.39 4,052.26 3,819.06 4,716.80 -2,561.62 2,263,011.25 229,254.06 2.57 5,365.98 MWD+SC+sag(3) 7,504.07 17.41 336.55 4,083.90 3,850.70 4,726.16 -2,565.70 2,263,020.71 229,250.19 2.92 5,376.17 MWD+SC+sag(4) 7,567.02 15.59 338.95 4,144.26 3,911.06 4,742.70 -2,572.49 2,263,037.39 229,243.77 3.09 5,393.98 MWD+SC+sag(4) 7,627.74 14.73 341.34 4,202.86 3,969.66 4,757.63 -2,577.89 2,263,052.44 229,238.71 1.75 5,409.73 MWD+SC+sag(4) 7,689.02 14.84 341.73 4,262.11 4,028.91 4,772.46 -2,582.84 2,263,067.38 229,234.09 0.24 5,425.19 MWD+SC+sag(4) 7,751.58 15.05 342.39 4,322.56 4,089.36 4,787.81 -2,587.81 2,263,082.83 229,229.46 0.43 5,441.12 MWD+SC+sag(4) 7,805.00 15.17 342.56 4,374.13 4,140.93 4,801.09 -2,592.00 2,263,096.20 229,225.57 0.24 5,454.85 MWD+SC+sag(4) Top of Fish 7,813.51 15.19 342.59 4,382.34 4,149.14 4,803.22 -2,592.67 2,263,098.34 229,224.95 0.24 5,457.04 MWD+SC+sag(4) 7/16/2015 6:42:37PM Page 5 COMPASS 5000.1 Build 73 • • . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Blossom#1 Project: Ninilchik Unit TVD Reference: Actual:Blossom#1 @ 233.20usft Site: Blossom MD Reference: Actual:Blossom#1 @ 233.20usft Well: Blossom#1 North Reference: True Wellbore: Rig:Blossom#1 Survey Calculation Method: Minimum Curvature Design: Blossom#1 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) (1100) (ft) Survey Tool Name 7,876.12 15.35 338.83 4,442.74 4,209.54 4,818.77 -2,598.12 2,263,114.01 229,219.85 1.60 5,473.37 MWD+SC+sag(4) 7,938.77 15.22 338.76 4,503.18 4,269.98 4,834.17 -2,604.09 2,263,129.54 229,214.22 0.21 5,489.80 MWD+SC+sag(4) 7,999.47 15.35 339.74 4,561.73 4,328.53 4,849.13 -2,609.76 2,263,144.63 229,208.89 0.48 5,505.70 MWD+SC+sag(4) 8,061.72 16.04 337.06 4,621.66 4,388.46 4,864.78 -2,615.96 2,263,160.41 229,203.03 1.61 5,522.46 MWD+SC+sag(4) 8,123.77 15.81 338.01 4,681.33 4,448.13 4,880.51 -2,622.47 2,263,176.28 229,196.88 0.56 5,539.43 MWD+SC+sag(4) 8,185.66 16.58 335.67 4,740.76 4,507.56 4,896.38 -2,629.27 2,263,192.30 229,190.44 1.63 5,556.64 MWD+SC+sag(4) 8,247.54 16.23 336.73 4,800.12 4,566.92 4,912.37 -2,636.32 2,263,208.44 229,183.74 0.74 5,574.09 MWD+SC+sag(4) 8,308.15 17.42 335.71 4,858.14 4,624.94 4,928.42 -2,643.40 2,263,224.64 229,177.02 2.02 5,591.60 MWD+SC+sag(4) 8,369.40 18.26 335.57 4,916.44 4,683.24 4,945.51 -2,651.14 2,263,241.90 229,169.67 1.37 5,610.34 MWD+SC+sag(4) 8,430.50 18.15 336.20 4,974.49 4,741.29 4,962.93 -2,658.94 2,263,259.50 229,162.26 0.37 5,629.41 MWD+SC+sag(4) 8,495.41 18.34 336.04 5,036.13 4,802.93 4,981.52 -2,667.16 2,263,278.26 229,154.45 0.30 5,649.69 MWD+SC+sag(4) 8,555.67 19.35 336.87 5,093.16 4,859.96 4,999.36 -2,674.94 2,263,296.27 229,147.08 1.73 5,669.12 MWD+SC+sag(4) 8,616.67 19.51 337.27 5,150.69 4,917.49 5,018.05 -2,682.84 2,263,315.13 229,139.59 0.34 5,689.36 MWD+SC+sag(4) 8,677.65 19.55 336.85 5,208.16 4,974.96 5,036.82 -2,690.79 2,263,334.08 229,132.07 0.24 5,709.69 MWD+SC+sag(4) 8,741.33 19.01 336.53 5,268.27 5,035.07 5,056.13 -2,699.11 2,263,353.57 229,124.18 0.86 5,730.67 MWD+SC+sag(4) 8,806.00 19.99 336.33 5,329.23 5,096.03 5,075.92 -2,707.74 2,263,373.54 229,115.99 1.52 5,752.21 MWD+SC+sag(4) 8,867.55 20.71 337.31 5,386.94 5,153.74 5,095.60 -2,716.16 2,263,393.40 229,108.01 1.29 5,773.56 MWD+SC+sag(4) 8,928.11 20.47 337.59 5,443.63 5,210.43 5,115.26 -2,724.33 2,263,413.24 229,100.28 0.43 5,794.79 MWD+SC+sag(4) 8,990.34 20.67 337.54 5,501.89 5,268.69 5,135.47 -2,732.67 2,263,433.64 229,092.39 0.32 5,816.58 MWD+SC+sag(4) 9,053.00 20.75 338.03 5,560.50 5,327.30 5,155.99 -2,741.05 2,263,454.33 229,084.47 0.30 5,838.66 MWD+SC+sag(4) 9,115.63 20.77 338.70 5,619.06 5,385.86 5,176.62 -2,749.24 2,263,475.14 229,076.75 0.38 5,860.76 MWD+SC+sag(4) 9,177.63 20.50 338.19 5,677.09 5,443.89 5,196.95 -2,757.26 2,263,495.64 229,069.18 0.52 5,882.50 MWD+SC+sag(4) 9,239.31 20.65 340.57 5,734.83 5,501.63 5,217.23 -2,764.89 2,263,516.09 229,062.00 1.38 5,904.03 MWD+SC+sag(4) 9,301.09 20.41 340.68 5,792.69 5,559.49 5,237.67 -2,772.08 2,263,536.68 229,055.27 0.39 5,925.50 MWD+SC+sag(4) 9,363.31 20.18 341.21 5,851.05 5,617.85 5,258.07 -2,779.13 2,263,557.23 229,048.68 0.47 5,946.87 MWD+SC+sag(4) 9,424.62 20.02 340.61 5,908.62 5,675.42 5,277.98 -2,786.02 2,263,577.29 229,042.24 0.43 5,967.73 MWD+SC+sag(4) 9,487.34 20.30 340.76 5,967.50 5,734.30 5,298.38 -2,793.17 2,263,597.84 229,035.55 0.45 5,989.15 MWD+SC+sag(4) 9,549.30 20.32 340.71 6,025.61 5,792.41 5,318.68 -2,800.26 2,263,618.30 229,028.91 0.04 6,010.45 MWD+SC+sag(4) 9,611.88 20.65 340.55 6,084.23 5,851.03 5,339.34 -2,807.53 2,263,639.12 229,022.11 0.53 6,032.15 MWD+SC+sag(4) 9,671.91 19.53 340.05 6,140.61 5,907.41 5,358.75 -2,814.48 2,263,658.68 229,015.59 1.89 6,052.59 MWD+SC+sag(4) 9,734.82 19.53 340.10 6,199.90 5,966.70 5,378.53 -2,821.64 2,263,678.61 229,008.87 0.03 6,073.46 MWD+SC+sag(4) 9,796.42 18.90 340.75 6,258.07 6,024.87 5,397.63 -2,828.44 2,263,697.85 229,002.50 1.08 6,093.56 MWD+SC+sag(4) 9,859.09 18.69 341.17 6,317.39 6,084.19 5,416.71 -2,835.02 2,263,717.08 228,996.34 0.40 6,113.54 MWD+SC+sag(4) 9,861.79 18.72 341.19 6,319.95 6,086.75 5,417.53 -2,835.30 2,263,717.91 228,996.08 1.06 6,114.40 MWD+SC+sag(4) Blossom 1-BHL tgt 9,920.68 19.33 341.58 6,375.62 6,142.42 5,435.72 -2,841.43 2,263,736.23 228,990.36 1.06 6,133.39 MWD+SC+sag(4) 9,982.43 19.17 342.15 6,433.92 6,200.72 5,455.07 -2,847.77 2,263,755.71 228,984.46 0.40 6,153.49 MWD+SC+sag(4) 10,044.63 18.89 339.31 6,492.72 6,259.52 5,474.21 -2,854.45 2,263,775.00 228,978.20 1.56 6,173.58 MWD+SC+sag(4) 10,106.99 19.70 337.86 6,551.58 6,318.38 5,493.39 -2,861.98 2,263,794.34 228,971.10 1.51 6,194.08 MWD+SC+sag(4) 10,168.62 19.17 338.07 6,609.70 6,376.50 5,512.40 -2,869.68 2,263,813.52 228,963.83 0.87 6,214.50 MWD+SC+sag(4) 7/16/2015 6:42:37PM Page 6 COMPASS 5000.1 Build 73 • • . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Blossom#1 Project: Ninilchik Unit TVD Reference: Actual:Blossom#1 @ 233.20usft Site: Blossom MD Reference: Actual:Blossom#1 @ 233.20usft Well: Blossom#1 North Reference: True Wellbore: Rig:Blossom#1 Survey Calculation Method: Minimum Curvature Design: Blossom#1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,230.86 19.14 339.09 6,668.49 6,435.29 5,531.41 -2,877.13 2,263,832.69 228,956.80 0.54 6,234.82 MWD+SC+sag(4) 10,292.81 19.22 339.61 6,727.00 6,493.80 5,550.46 -2,884.31 2,263,851.89 228,950.05 0.30 6,255.05 MWD+SC+sag(4) 10,354.73 18.71 340.86 6,785.56 6,552.36 5,569.39 -2,891.12 2,263,870.97 228,943.67 1.05 6,275.00 MWD+SC+sag(4) 10,415.30 19.50 339.00 6,842.80 6,609.60 5,588.01 -2,897.93 2,263,889.73 228,937.28 1.65 6,294.67 MWD+SC+sag(4) 10,478.91 19.75 338.03 6,902.71 6,669.51 5,607.89 -2,905.75 2,263,909.78 228,929.90 0.65 6,315.93 MWD+SC+sag(4) 10,541.69 20.14 337.76 6,961.73 6,728.53 5,627.73 -2,913.81 2,263,929.80 228,922.28 0.64 6,337.27 MWD+SC+sag(4) 10,603.73 20.59 337.60 7,019.89 6,786.69 5,647.70 -2,922.01 2,263,949.95 228,914.53 0.73 6,358.78 MWD+SC+sag(4) 10,665.86 18.80 338.42 7,078.38 6,845.18 5,667.11 -2,929.86 2,263,969.53 228,907.12 2.92 6,379.63 MWD+SC+sag(4) 10,728.60 18.28 339.83 7,137.87 6,904.67 5,685.75 -2,936.97 2,263,988.32 228,900.43 1.09 6,399.46 MWD+SC+sag(4) 10,791.96 18.18 341.11 7,198.05 6,964.85 5,704.43 -2,943.60 2,264,007.14 228,894.22 0.65 6,419.11 MWD+SC+sag(4) 10,855.21 19.21 339.54 7,257.96 7,024.76 5,723.51 -2,950.43 2,264,026.37 228,887.81 1.81 6,439.21 MWD+SC+sag(4) 10,916.81 18.50 340.50 7,316.25 7,083.05 5,742.22 -2,957.23 2,264,045.23 228,881.43 1.26 6,458.96 MWD+SC+sag(4) 10,977.85 18.71 340.36 7,374.10 7,140.90 5,760.57 -2,963.76 2,264,063.72 228,875.32 0.35 6,478.26 MWD+SC+sag(4) 11,039.87 19.02 339.38 7,432.79 7,199.59 5,779.40 -2,970.66 2,264,082.70 228,868.84 0.71 6,498.17 MWD+SC+sag(4) 11,102.01 18.15 341.34 7,491.69 7,258.49 5,798.04 -2,977.32 2,264,101.49 228,862.59 1.72 6,517.80 MWD+SC+sag(4) 11,166.86 17.81 343.41 7,553.37 7,320.17 5,817.12 -2,983.38 2,264,120.69 228,856.95 1.12 6,537.54 MWD+SC+sag(4) 11,200.00 17.81 343.41 7,584.93 7,351.73 5,826.83 -2,986.28 2,264,130.47 228,854.28 0.00 6,547.51 PROJECTED to TD 5"-Blossom#1 PBI TD Checked By: am"Whee'er@haIhburt°n.c Approved By: Chelsea Gvi'-(g ht Date: 7/16/2015 6:42:37PM Page 7 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Blossom#1 Date 27-May-15 County Kenai Peninsula Borough State Alaska Supv. Shane Hauck/Lenward Toussant CASING RECORD Sear TD 2506.00 Shoe Depth: 2495.26 PBTD: 2390' Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 103/4 BTC WFD 1.90 2,495.26 2,493.36 2 Jnts 10 3/4 45.5 1-80 BTC 81.47 2,452.41 2,411.89 Flt Clr 10 3/4 BTC WFD 1.48 2,411.89 2,410.41 59 10 3/4 45.5 1-80 BTC 2,385.39 63.99 25.02 Hgr w/pup 10 3/4 45.5 L-80 BTC Seaboard 3.02 25.02 22.00 Landing jnt 103/4" BTC 22.00 22.00 0.00 Totals 61 into. Csg Wt.On Hook: 41 Type Float Collar: Model 402 No.Hrs to Run: 11.5 Csg Wt.On Slips: 34 Type of Shoe: Bull Nose/303 Casing Crew: WFD Fluid Description: 9.3 ppg Spud Mud,PV 34,YP 27 Liner hanger Info(Make/Model): Liner top Packer?: Yes X No Liner hanger test pressure: 0 Centralizer Placement: 2 bowspring on shoe jnt,1 centralizer middle bakerlok jnt, 1 centralizers every other jnt(30 total) CEMENTING REPORT Preflush(Spacer) !Type: Mud Push II Density(ppg) 10 Volume pumped(BBLs) 45 Lead Slurry Type: Extended Density(ppg) 11.9 Volume pumped(BBLs) 277 ° Mixing/Pumping Rate(bpm): 5 .Tail Slurry Type: Conventional Density(ppg) 15.4 Volume pumped(BBLs) 52 Mixing/Pumping Rate(bpm): 5.4 w Post Flush(Spacer) m Type:Fresh Water Density(ppg) 8.3 Rate(bpm): 5 Volume: 20 ix LL Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 6 Volume(actual/calculated): 231/232 FCP(psi): 700 Pump used for disp: SLB Plug Bumped? X Yes No Bump press 1200 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 78 Cement returns to surface? x Yes No Spacer returns? X Yes No Vol to Surf: 31 Cement In Place At: 17:45 PM Date: 5/27/2015 Estimated TOC: 0 Method Used To Determine TOC: PSIG/PH samples Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry Ju Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: wDisplacement: 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: WELLHEAD Make Type Serial No. Size W.P. Test Head To PSIG MIN OK Remarks: This particular report pertains to the Surface Casing and Cement i i Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Ninilchik,Blossom 1 Date 8-Jun-15 County Kenai PB State Alaska Supv. Shane Hauck/Douglas Yessak CASING RECORD `jr C 45t"-' TD 6795.00 Shoe Depth: 6785.42 PBTD: 6700.00 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom _ Top shoe 75/8 _ BTC _ Weatherford 1.64 6,785.42 6,783.78 2 jts _ 7 5/8 29.7 L-80 BTC 82.45 6,783.78 6,701.33 Float collar 7 5/8 BTC _ Weatherford 1.34 6,701.33 _ 6,699.99 166 7 5/8 29.7 L-80 BTC 6,760.32 6,699.99 22.12 1 PUP JT 7 5/8 L-80 BTC 1 2.19 22.12 19.93 Hanger 16 3/4 x 11 Seaboard 0.56 19.93 19.37 _ RKB 20.20 19.37 0.00 0.00 0.00 _ 0.00 0.00 Totals 168 Csg Wt.On Hook: 112,000 Type Float Collar: Weatherford#303 No.Hrs to Run: 14.5 hrs Csg Wt.On Slips: 58,000 Type of Shoe: Weatherford#402 Casing Crew: Weatherford Fluid Description: 9.35 ppg KCL Drilling mud PV 15,YP 21 Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: 80'spacing,41 ran,top centralizer on jt#91 at 3172 ft. CEMENTING REPORT 2--14 4" Preflush(Spacer) Type: Mud push 2 Density(ppg) 11 Volume pumped(BBLs) 34 Lead Slurry ' 64`' '- j[r' Type: class G J (� Density(ppg) 13.5 Volume pumped(BBLs) 4 Mixing/Pumping Rate(bpm): 5 Tall Slurry Type: Neat,class G 0 Density(ppg) 15.3 Volume pumped(BBLs) 52 Mixing/Pumping Rate(bpm): 5 N Post Flush(Spacer) y Type: Density(ppg) Rate(bpm): Volume: o: LL Displacement: Type: Drilling mud Density(ppg) 9.3 Rate(bpm): 5 Volume(actual/calculated): 301/311 FCP(psi): 600 Pump used for disp: SLB Plug Bumped? _Yes X No Bump press Casing Rotated? Yes X No Reciprocated? Yes X No 100%Retums during job Cement retums to surface? Yes X No Spacer returns? X Yes No Vol to Surf: Trace of spacer Cement In Place At: 14:58 Date: 6/8/2015 Estimated TOC: 2,085 Method Used To Determine TOC: Calculated Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: w 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: WELLHEAD Make Sea board Type Multi bowl Serial No. H361958 Size 16 3/4 x 11 W.P. 3M X 5M Test Head To 5000 PSIG 15 MIN test OK Remarks: Plug did not bump,Float held • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Ninilchik,Blossom 1 Date 14-Jul-15 County Kenai PB State Alaska Supv. Rance Pederson/Doug Yessak CASING RECORD TD 11200.00 Shoe Depth: 11198.00 PBTD: 11074.02 Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top shoe 5 x 4 1/2 DWC/C Weatherford 2.25 11,198.00 11,195.75 2 Joints 41/2 12.6 L-80 DWC/C USS 79.44 11,195.75 11,116.31 Float collar _ 5 x 4 1/2 DWC/C Weatherford 1.36 11,116.31 11,114.95 1 Joint _ 41/2 12.6 L-80 DWC/C USS 39.91 11,114.95 11,075.04 Landing Collar 5 x 4 1/2 DWC/C J Hobbs 1.02 11,075.04 _ 11,074.02 109 jots/5 RA pups 41/2 12.6 _ L-80 DWC/C USS 4,450.73 11,074.02 6,623.29 Liner Hanger 5 1/2 x 7 s/a DWC/C Baker 59.90 6,623.29 6,563.39 Totals 24 Csg Wt.On Hook: 195 Type Float Collar: Weatherford#402E No.Hrs to Run: 14.5 hrs Csg Wt.On Slips: Type of Shoe: Weatherford Reamer Casing Crew: Weatherford Fluid Description: 10.0 ppg 6%KCL Drilling mud PV 14,YP 22 Liner hanger Info(Make/Model): Baker/HRD-E ZXP RS Flex-Lock Liner top Packer?: X Yes_No Liner hanger test pressure: 1500 psi Centralizer Placement: 40'spacing,Ran 112 Hydroform Centralizers CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 12.5 Volume pumped(BBLs) 21 Lead Slurry Type: Class"G"Easy Blok Density(ppg) 15.3 Volume pumped(BBLs) 175 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: N/A Ltel Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): y Post Flush(Spacer) ) Type: Density(ppg) Rate(bpm): Volume: o: LL Displacement: Type: 6%KCL Mud Density(ppg) 10 Rate(bpm): 6 Volume(actual/calculated): 159/159 FCP(psi): 1500 Pump used for disp: SLB Plug Bumped? X Yes No Bump press 4600 Casing Rotated? Yes X No Reciprocated? X Yes No %Retums during job 80 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 4:30 Date: 7/14/2015 Estimated TOC: 6,563 n N) Method Used To Determine TOC: (ef a�_ r T / Preflush(Spacer) 61-2-1.. —7/7J/" Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): Tail Slurry w Type: a Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): 1– u? Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: NDisplacement: 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: WELLHEAD Make Sea board Type Multi bowl Serial No. H361958 Size 16 3/4 x 11 W.P. 3M X 5M Test Head To 5000 PSIG 15 MIN test OK Remarks: Did not get excess MudPush or cement to surface despite having pumped 175 bbls and intermitant returns • • I •I a 379.0' A FEL • I BLOSSOM#1 WELL • AS-BUILT I NAD27 ASP ZONE 4 • N:2258238.57' I E:231709.77' LAT:60°10'23.6840"N LON: 151°28'24.1804"W I ELEV=215.2"NGVD29 SECTION 14 T1N,R13W,AK 1059.1'FSL,379.0'FEL • W _ .Z u-) IJ Z o •O Io .W I •1 SECTION 14 T1N R13W I SECTION 13 T1N R13W • I N:2257171.15 �.. �E:232064.34 �. SECTION LINE SECTION LINE •• SECTION 23 T1N R13W SECTION 24 T1N R13W I • tt COy Z %* �{ ,t% 1 NOTES . STAN A.MCLANE • 1.BASIS OF GEODETIC CONTROL AND NAD83 POSITION(EPOCH 4637-5 - 2003)IS AN OPUS SOLUTION FROM NGS STATIONS"KEN5 CORS //1 3/13/15 ARP","ZAN1 CORS ARP",AND"TSEA ARP"TO ESTABLISH THE ttl ll�""�%�� POSITION OF NGS CONTROL STATION PAT 1979 RM 1.THE GEODETIC POSITION OF PAT 1979 RM 1 WAS DETERMINED TO HAVE A LATITUDE OF 60°09'48.70932"N AND A LONGITUDE OF 151°29'27.84397"W.THE ALASKA STATE PLANE COORDINATES(ASP) ZONE 4 NAD 83 FEET ARE: fV = N=2,254,726.735 E=1,368,837.058 NORTH ELEV. 162.40'(NGVD29) g11 2.SECTION LINES SHOWN WERE ESTABLISHED FROM SURVEY TIES TO ORIGINAL GLO MONUMENTATION(1987) SCALE 0 300 600 3. DATA TRANSFORMATIONS(NAD83 TO NAD27 ASPZ4)WERE I FEET I DONE USING CORPSCON VERSION 6.0.1. .11 BLOSSOM #1 WELL AS-BUILT SURFACE LOCATION (NAD27) H LOCATION: SECTION 14, TOWNSHIP 1 NORTH, ik ENGINEERING-TESTING RANGE 13 WEST, SEWARD MERIDIAN ALASKA SURVEYING-MAPPING P.O.BOX 468 IIileorp AlaAit. 1.1,1: MSC, SOLDOTNA,AK.99669 JOB NO. 143154 REV. 1 VOICE:(907)283-4218 FAX:(907)283-3265 BY Consul:lihg Inc WWW.MCLANECG.COM BGB Date: 4/28/15 FIGURE: 1 �o�Report CemCAT v1.5 Cementing Schlumberger p Well Blossom-1 —C S ''vL(� Client HILCORP Field Blossom SIR No. CT3V-00042 Engineer Leon/Isaac/Donny Job Type 7 5/8 Intermediate Casing United States 06-08-2015 Time Pressure Rate Density Volume Messages wratna.usa 10:02:15 Chloride=50oppm pH e<7.7 10:27:00 Cement head cg up 10:52:00 11:17:00 Pre-job safety meeting r Air blown down the HP line Start pumping l5bbl to flush Reset Total,Vol=0.23 bbl 11:42:00 - - Pump at 2,3 bonn Start Pumping Wash lobblaway Stop @ 15bbl pumped Reset Total,Vol=16.03 bbl Low stall PT 12:07:00 trip checked tip checked High Pressure 0 4700ps1 Bleed Off Pressure Start pumping MudPush I2 12:32:00 lObbl away 0 5bpm Start batching slurry Stop pumping MudPush II 0 67 5 dropped the bottom plug,gone ok Start pumping Lead downhole Remark 12:57:00 20 bbl away 30 bbl away 50bbl away and 30bbi of mix fluid 60 bbl away 0 4.5bpm 80bblaway 50bbl of mixed fluid All 13:22:00 sams taken for lead 100 bPaeway a 4.5BPM w/250p: 120bbl away TSL 150bbl away p 190p51 w/806b1 ^^ 16Obbl away Of 220psi 13:47:00 ���I'l 180b. ix at y tir 175bbl si i85bbi total Lead Reset Total,Vol=186.07 bbl Reset Total,Vol=5.38 bbl 14:12:00 matc Switchhing to tadTail sluslurry,rry start mixing.. up Start pumping tail Di / • 15.3#of tall sample taken lObbl away 0300psl,15# 20bbl away 14:37;00 30bbl away 7/111--- SObbl away at 270psi 54bbl total TAIL Reset Total,Vol=53.76 bbl Top plug dropped Displacement started with 10bbi F 10 of waterl 15:02:00 ResetlTotal,Vol 111 .08 bbl Start pumping mud for dispiaceme 30 bbl away 70bbl away displacement rate dropped for not full return et 15:27:00 from 6.78PM to 4.6 BPM 160bblaway All ant head valves open pins ba+ 220 bbl away displacement l 270bb1 away®550ps1 Trace of mudPush at surface 15:50:37 — 280 bbl away w/600psi 290 bbl away Slow rate down at 3BPM hh,mnf:ss 0'm 11W i600 3300 52A0 {S00 0.00 LO SA 7s 140 3.0 10.0 0.0 20.0 *0 0.01 1*0 20.5 ASA IMO .w..wsr (. _. PSi - B/M ] -tJ�/ BBI. 06/09/2015 11:21:26 • • Blossom #1 Days vs Depth 0 500 EMI" —Blossom#1 Actual — 1000 ■ . Blossom#1 Plan 1500 ■'■ 2000 is 2500 3000 3500 4000 4500 5000 F 5500 a 6000 ai v 6500 L in 7000 ........ CO ai 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 0 10 20 30 40 50 60 70 Days • Blossom #1 MW vs Depth o Blossom#1 Plan 1000 Blossom#1 Actual 2000 3000 4000 5000 r v 6000 v 7 W 7000 8000 9000 10000 - 11000 12000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) LOF Tye %%icesv THE STATE Alaska Oil and Gas AT ASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®FALASY`P- Fax: 907.276,7542 www.aogcc.alaska.gov Taylor Nasse Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Blossom#1 Sundry Number: 315-572 Dear Mr. Nasse: 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, /46V4 -t4V('- Cathy P Foerster Chair DATED this 7 day of October, 2015 Encl. RBpMg OCT 131015 0 0 RECEIVE STATE OF ALASKA SEP 1 7^ ?015 6/4S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 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:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development E . 215-015 • 3.Address. 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service F.1 6.API Number. Anchorage,Alaska 99503 50-133-20648-00 _: 7.If perforating: 8.Well Name and Number. t> What Regulation or Conservation Order governs well spacing in this pool? CO 701 Blossom#1 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10. Field/Pool(s): • Fee-Private(Ninilchik Unit Tract 3)/ADL 389737 Ninilchik Field Beluga/Tyonek 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): 11,198 7,555 11,074 7,439 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 2,495' 10-3/4" 2,495' 1,586' 5,210 psi 2,470 psi Intermediate Production 6,785' 7-5/8" 6,785' 3,406' 6,890 psi 4,790 psi Liner 4,635' 4-1/2" 11,198' 7,555' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4-1/2" 12.6#/L-80 6,563 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer;N/A 6,563'MD/3,197'TVD;N/A 12.Attachments: Description Summary of Proposal 0 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: 10/1/2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS E . WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown LI Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasse(cr�hilcorp.com Printed Name Taylor Nasse Title Operations Engineer / --... -e/f/\ Signature oneg907-777-8354 Date (7,/ / )//S COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' IS—S-12— Plug 15—S—f2Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: d - .--/ G--11 RBDMSWCI 1 3 111 90,64....3(74.A APPROVED BYOApproved by: COMMISSIONER THE COMMISSION Date: —g"/S /. /� s from m / th s Submit Form and Form 10-403 Revised 5/2015 I{idly Rice p t r valid for months from the date of approval. Attachments in Duplicate , 743/0— ( p.-.3,i("- S • Well Prognosis Well: Blossom#1 Hilcorp Alaska,LL Date: 9/17/2015 Well Name: Blossom#1 API Number: 50-133-20648-00 Current Status: Perforated, not producing Leg: Estimated Start Date: October 1, 2015 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-015 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (C) AFE Number: 1413217C Estimated Bottom Hole Pressure: —3,199 psi at 7,439' TVD (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,455 psi (0.10 psi/ft gas gradient) Brief Well Summary Blossom#1 is a grass roots well that is currently completed and perforated but is not currently producing. The well consists of 10-3/4" surface casing and 7-5/8" production casing with 4-1/2" liner/liner packer and 4-1/2" tie-back tubing. Objective of Work Add perforations in the Tyonek sands. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. 2. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton MAD Pass log dated July 12th, 2015. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek T18 ±10,392 ±10,408 ±16 4. POOH. 5. Flow well through test separator and record water and gas rates. 6. If any of the Tyonek sands are not commercial, then the zone will be plugged back with a bridge plug. 7. RD e-line. 8. Turn well over to production. Attachment: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Ninilchik Unit Well: Blossom#1 5 CURRENT SCHEM, H di. ATIC API:D 50-133-20648-00 Hilcorp Alaska,LLC CASING DETAIL l6"J 1 2 ,Xti Size Type Wt Grade Conn. ID Top Btm 16" Conductor 84 X-56 Weld 15.010" Surf 110' 10-3/4" Surf.Csg 45.5 L-80 BTC 9.950" Surf 2,495' 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 6,785' 4-1/2" Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,563' 11,198' 3 ( TOC @ TUBING DETAIL 10-3/4"h of 2,000' 4-1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,563' ro r. i JEWELRY DETAIL 1 4No. Depth ID OD Item ..4r+' 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" 6 2 19' 3.958" 4.500" Pup Joint 7_5/8" wi ' 3 2,019' 3.813" 6.500" 4-1/2"Chemical Injection Mandrel LJI 4 6,563' 3.958" 4.500" 4-1/2"Seal Assembly Shoe @ 6,785' - 5 6,563' 4.500" 6.500" Liner Tie-Back Receptacle 6 6,563' 5.000" 6.672" Liner Top Packer RA Mkr Jt7 10,485' CIBP 8,207' ' y`'. 4'1 4 RAMkrJt ,'`I 8,780' q.,,, .. , RA Mkr Jt , �,�` PERFORATION DETAIL 9,984' .i". Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status -4 8134 8,345 8,365 4,893 4,912 9/4/15 2-7/8" Open RA Mkr Jt T3 __ 8,844 8,874 5,365 5,393 9/3/15 2-7/8" Open 10,203' I ** T13 9,900 9,930 6,356 6,384 9/2/15 2-7/8" Open " T17 10,324 10,340 6,757 6,772 9/1/15 2-7/8" Open T28 10,492 • 10,512 6,915 6,934 8/2/15 2-7/8" Isolated RA Mkr Jt ' a. T28 10,536 . 10,561 6,956 6,980 8/2/15 2-7/8" Isolated T28 10,580 10,610 6,988 7,026 8/2/15 2-7/8" Isolated 10,697 T50 10,971 . 10,986 7,368 7,382 8/1/15 2-7/8" Isolated B134 • -r- - T3 T13 "'. T17 , ' "' T28 ' T50 4-1/2" - : 4 . Shoe @ 11,198'-6-3/4"hole PBTD=11,074'MD/7,439'TVD TD=11,198'MD/7,555'TVD Max Deviation:75 deg Max Dogleg:4 deg/100 Updated by TWN 09-17-15 Ai!, Ninilchik Unit Well: Blossom#1 PROPOSED SCHEM• in . ATIC APIO 50-133-20648-000 Hilcorp Alaska,LLC CASING DETAIL t 16„1 2 Size Type Wt Grade Conn. ID Top Btm 16" Conductor 84 X-56 Weld 15.010" Surf 110' 10-3/4" Surf.Csg 45.5 L-80 BTC 9.950" Surf 2,495' 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 6,785' ..st 3'4-1/2" Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,563' 11,198' 3 f 1. " TOC @ TUBING DETAIL 10-3/4" ,,,, 2,000' 4-1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,563' 9w ..4 .0 JEWELRY DETAIL 1 4 4 No. Depth ID OD Item 5 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" 6 2 19' 3.958" 4.500" Pup Joint 7_5/8" Q+ ",., k, , 3 2,019' 3.813" 6.500" 4-1/2"Chemical Injection Mandrel L. 4 6,563' 3.958" 4.500" 4-1/2"Seal Assembly Shoe @ 6,785' - 5 6,563' 4.500" 6.500" Liner Tie-Back Receptacle 6 6,563' _ 5.000" 6.672" Liner Top Packer RA Mkr Jt ' 7 10,485' CIBP 8,207' ' f j , RAMkrJt ' 2 8,780' RA Mkr Jt ', •a PERFORATION DETAIL 9,984' Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status .. B134 8,345 8,365 4,893 4,912 9/4/15 2-7/8" Open 13 8,844 8,874 5,365 5,393 9/3/15 2-7/8" Open 110,03' Jt , * T13 9,900 9,930 6,356 6,384 9/2/15 2-7/8" Open ' 117 10,324 10,340 6,757 6,772 9/1/15 2-7/8" Open T18 10,392 6,821 6,836 2/7/8" Proposed RA Mkr Jt * T28 10,492 10,512 6,915 6,934 8/2/15 2-7/8" Isolated T28 10,536 10,561 6,956 6,980 8/2/15 2-7/8" Isolated 10,697' T28 10,580 10,610 6,988 7,026 8/2/15 2-7/8" Isolated T50 10,971 10,986 7,368 7,382 8/1/15 2-7/8" Isolated R _- __,- B134 , -,--- T3 T13 'T i -=r- T18 . '4- T28 `' , T50 4-1/2" i Shoe @ 11,198'-6-3/4"hole PBTD=11,074'MD/7,439'TVD TD=11,198'MD/7,555'TVD Max Deviation:75 deg Max Dogleg:4 deg/100 Updated by TWN 09-17-15 215015 Sea°Ian Hilcorp Alaska, LL� GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Ililrn�p AlaAn.Ll I Fax: 907 777-8510 DATA LOGGED E-mail: snolan@hilcorp.com "C/242015 M. K BEND DATE 08/24/15 RECEIVED To: Alaska Oil & Gas Conservation Commission AUG 2 5 2015 Makana Bender AOGCC Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTA Blossom 1 and PB1 Elog and Mudlog data Prints Blossom 1: 76 1 49 ROP-DGR-ALD-ALD Image and Dip Plot MD, ROP-DGR-PCG-EWR-ADR-ALD-CTN 2" and 5"MD, ROP- DGR-EWR-ALD-CTN-ALD Image 2" and 5" MD, DGR-PCG-EWR-ADR-ALD-CTN 2" and 5"TVD Formation Evaluation Log 2" and 5" MD, Drilling Engineering Lo 2" MD, Gas Ratio Log 2" MD End of Well Report (Blossom 1 and Blossom 1 PB1) 2 6 1 5 1 (1615 2 ,) Prints Blossom 1 PB1: 26 1 5 0 ROP-DGR-PCG-EWR-ADR-ALD-CTN 2" and 5" MD, DGR-PCG-EWR-ADR-ALD-CTN 2" and 5"TVD, Formation Evaluation Log 2" and 5" MD, Drilling Engineering Log 2" MD, Gas Ratio Log 2" MD CD 1: Blossom 1+PB 1_DATA_D'VD 8/14/2015 2:07 PM File folder Blossom 1 CGhl 8/14/2015 2:06 PM File folder Definitive Survey 8/14/2015 2:06 PM File folder DLIS+LAS 8/14/2015 2:06 PM File folder EMF 8/14/2015 2:06 PM File folder PDF 8/14/2015 2:06 PM File folder TIFF 8/14/2015 2:07 PM File folder Blossom 1 PB1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received ✓� Date: Seeolan Hilcorp Alaska, LL• GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Alaska.i.i. Fax: 907 777-8510 E-mail: snolan@hilcorp.com CGM 8/14/2015 2:07 PM File folder Definitive Survey 8/14/2015 2:08 PM File folder DLIS+LAS 8/14/2015 2:08 PM File folder EMF 8/14/2015 2:08 PM File folder PDF 8/14/2015 2:08 PM File folder TIFF 8/14/2015 2:08 PM File folder CD 2: Files Currently on the Disc(7) Blossom 1 FINAL LOGS 8/5/2015 3:23 PM File folder Blossom 1 LAS EXPORTS 8/5/2015 3:23 PM File folder ,. Blossom 1 PB 1 FINAL LOGS 8/5/20153:23 PM File folder y , Blossom 1 PB 1 LAS EXPORTS 8/5/2015 3:23 PM File folder . EMF Log Viewer 8/5/2015 3:23 PM File folder Halliburton Log Vie.,er 8/5/2015 3:23 PM File folder Lig Blossom 1 FINAL END OF WELL REPORT 8/5/2015 12:38 PM PDF Document 4,036 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 Received By: '�./ Date: 21 50 15 Seikolan Hilcorp Alaska, LLC• GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 ILkiwis Uit.ku.las. Fax: 907 777-8510 DATA LOGGED E-mail: snolan@hilcorp.com 16i240i2o15 d K BENDER DATE 08/24/15 RECEIVED To: Alaska Oil & Gas Conservation Commission AUG 2 5 2015 Makana Bender AOGCC Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Blossom 1 and PB1 Elog and Mudlog data Prints Blossom 1: 4 9 ROP-DGR-ALD-ALD Image and Dip Plot MD, ROP-DGR-PCG-EWR-ADR-ALD-CTN 2" and 5"MD, ROP- DGR-EWR-ALD-CTN-ALD Image 2" and 5" MD, DGR-PCG-EWR-ADR-ALD-CTN 2" and 5"TVD Formation Evaluation Log 2" and 5" MD, Drilling Engineering Log 2" MD, Gas Ratio Log 2" MD End of Well Report (Blosso c d Blossom 1 PB1) 2 6 1 5 1 2 6 1 5 2 Prints Blossom 1 PB1: 2 6 1 5 0 ROP-DGR-PCG-EWR-ADR-ALD-CTN 2" and 5" MD, DGR-PCG-EWR-ADR-ALD-CTN 2" and 5" TVD, Formation Evaluation Log 2" and 5" MD, Drilling Engineering Log 2" MD, Gas Ratio Log 2" MD CD 1: Blossom 1+PB 1_DATA_DV D 8/14/2015 2:07 PM File folder Blossom 1 CGM 8/14/2015 2:06 PM File folder Definitive Survey 8/14/2015 2:06 PM File folder . DLIS+LAS 8/14/2015 2:06 PM File folder EMF 8/14/2015 2:06 PM File folder PDF 8/14/2015 2:06 PM File folder TIFF 8/14/2015 2:07 PM File folder Blossom 1 PB1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 ReceivedVk^`G Date: • Se lolan Hilcorp Alaska, LL GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 IfdIrnris %Inrka.l.I.t, Fax: 907 777-8510 E-mail: snolan@hilcorp.com CGM 8/14/2015 2:07 PM File folder . Definitive Survey 8/14/2015 2:08 PM File folder DLIS+LAS 8/14/2015 2:08 PM File folder . EMF 8/14/2015 2:08 PM File folder . PDF 8/14/2015 2:08 PM File folder . TIFF 8/14/2015 2:08 PM File folder CD 2: Files Currently on the Disc(7) Blossom 1 FINAL LOGS 8/5/2015 3:23 PM File folder Blossom 1.LAS EXPORTS 8/5/2015 3:23 PM Fle folder . Blossom 1 PB 1 FINAL LOGS 8/5/2015 3:23 PM File folder . Blossom 1.PB 1 LAS EXPORTS 8/5/2015 3:23 PM File folder EMF Log Viewer 8/5/2015 3:23 PM File folder Halliburton Log Viewer 8/5/2015 3:23 PM File folder In Blossom 1 FINAL END OF WELL REPORT 8/5/2015 12:38 PM PDF Document 4,0315 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 Received By: /0.d��ti '✓ Date: • • OF 771 OAP, I�js THE STATE Alaska Oil and Gas of Conservation Commission LAsKAL 40tE =;- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Taylor Nasse Operations Engineer Hilcorp Alaska, LLC i5- © i s 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Blossom#1 Sundry Number: 315-495 Dear Mr. Nasse: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this y of August, 2015 Encl. • ` RECEIVED STATE OF ALASKA AUG 122015 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 a ( 7/ 15 APPLICATION FOR SUNDRY APPROVALS AOC C 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:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development ❑✓ • 215-015 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 111 • 6.API Number: Anchorage,Alaska 99503 50-133-20648-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 Blossom#1 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): Fee-Private(Ninilchik Unit Tract 3)/ADL 389737 - Ninilchik Field-Beluga/Tyonek 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): 11,198 7,555 11,074 7,439 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 2,495' 10-3/4" 2,495' 1,586' 5,210 psi 2,470 psi Intermediate Production 6,785' 7-5/8" 6,785' 3,406' 6,890 psi 4,790 psi Liner 4,635' 4-1/2" 11,198' 7,555' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4-1/2" 12.6#/L-80 6,563 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer;N/A 6,563'MD/3,197'TVD; N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development ❑J Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 8/26/2015 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑✓ - WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasse@hilcorp.com Printed Name ff\ T loorrNasse Title Operations Engineer k,,- //� /�Signature ` Phone 907-777-8354 Date / i COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3(5— if`I 6 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Dr Subsequent Form Required: /D 1 ✓J9 APPROVED BY Approved by:a#.147 P ---4)...i_.,1--/V-1—......_ COMMISSIONER THE COMMISSION Date: 8_ / ) _ / _ //y/� Submit Form and Form 10-403 Revised 5/204 i rr� lid for 12 monthsllfrom the date of approval. Attachm nts in Duplicate •17_I 1"1"L ��CO'.3 - .-'fit`' s,'' ( . " —RBDMS 19 O1� �j AUG2 • S Well Prognosis • Well: Blossom#1 Hilcora Alaska,LL Date:8/11/2015 Well Name: Blossom#1 API Number: 50-133-20648-00 Current Status: Perforated, not producing Leg: Estimated Start Date: August 26, 2015 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-015 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 903-0341 (C) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (C) AFE Number: 1413217C Estimated Bottom Hole Pressure: —3,199 psi at 7,439' TVD (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,455 psi (0.10 psi/ft gas gradient) Brief Well Summary Blossom #1 is a grass roots well that is currently completed and perforated but is not currently producing. The well consists of 10-3/4" surface casing and 7-5/8" production casing with 4-1/2" liner/liner packer and 4-1/2" tie-back tubing. Objective of Work Add perforations in the Beluga and Tyonek sands. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. 2. If necessary, bleed pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Tyonek and Beluga sands with 2-7/8" 6 SPF 60 deg phased perf guns.All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton MAD Pass log dated July 12th, 2015. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Beluga B134 ±8,339 ±8,360 ±21 Tyonek T3 ±8,844 ±8,874 ±30 Tyonek T8 ±9,440 ±9,486 ±46 Tyonek T13 ±9,896 ±9,934 ±38 Tyonek T15 ±10,288 ±10,299 ±11 Tyonek T15 ±10,327 ±10,338 ±11 4. POOH. 5. Flow well through test separator and record water and gas rates. 6. If any of the Tyonek sands are not commercial, then the zone will be plugged back with a bridge plug. ' 7. RD e-line. , ll • • Well Prognosis Well: Blossom#1 Hilcorp Alaska,LL Date: 8/11/2015 8. Turn well over to production. Attachment: 1. Proposed Wellbore Schematic Ninilchik Unit Well: Blossom#1 . 13 PROPOSED SCH EMATI PTD:215-015 API: 50-133-20648-00 Hilrora Alaska,I,I.1: CASING DETAIL 16"J 2 L Size Type Wt Grade Conn. ID Top Btm 16" Conductor 84 X-56 Weld 15.010" Surf 110' 10-3/4" Surf. Csg 45.5 L-80 BTC 9.950" Surf 2,495' 3 ) TOC @ 7-5/8" Prod. Csg 29.7 L-80 BTC 6.875" Surf 6,785' 10-3/4"Z 2,000' 4-1/2" Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,563' 11,198' TUBING DETAIL 4-1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,563' JEWELRY DETAIL ( No. Depth ID OD Item 4 ^ 5 , 6 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" 2 19' 3.958" 4.500" Pup Joint 7-5/8" A 3 2,019' 3.813" 6.500" 4-1/2" Chemical Injection Mandrel Shoe @ 6,785' 4 6,563' 3.958" 4.500" 4-1/2"Seal Assembly RA MkrJt " ' 5 6,563' 4.500" 6.500" Liner Tie-Back Receptacle 8'207 6 6,563' 5.000" 6.672" Liner Top Packer RA MkrJt 8,780' ' ', 4, RA MkrJt , ' T.`.: PERFORATION DETAIL 9,984' MC Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Date Size Status B134 ±8,339 ±8,360 ±4,888 ±4,907 2-7/8" Proposed RA MkrJt ' n T3 ±8,844 ±8,874 ±5,365 ±5,393 2-7/8" Proposed 10,203' iii v T8 ±9,440 ±9,486 ±5,923 ±5,966 2-7/8" Proposed T13 ±9,896 ±9,934 ±6,352 ±6,388 2-7/8" Proposed RA MkrJt ' ►,l ' T15 . ±10,288 _ ±10,299 , ±6,722 ±6,733 2-7/8" Proposed 10,697' lai ` r6134 T15 ±10,327 ±10,338 ±6,759 ±6,770 2-7/8" Proposed T3 T28 10,492 10,512 6,915 6,934 8/2/15 2-7/8" Open -7 T8 T28 10,536 10,561 6,956 6,980 8/2/15 2-7/8" Open T28 10,580 10,610 6,988 7,026 8/2/15 2-7/8" Open mo. T13 T50 10,971 10,986 7,368 7,382 8/1/15 2-7/8" Open T15 -4- T18 T28 T50 6-3/4" hole 4-1/2" Shoe @ 11,198' PBTD=11,074'MD/7,439'TVD TD= 11,198'MD/7,555'TVD Max Deviation:75 deg Max Dogleg:4 deg/100 Downhole Proposed Updated by TWN 8/12/15 tiOF 7, re\� js THE STATE Alaska Oil and Gas „ Conservation Commission LAsi.(6.A. 333 West Seventh Avenue BILL WALKER Anchorage, Alaska 99501-3572 7e Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Taylor Nasse 15- © 1 E Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Blossom#1 Sundry Number: 315-435 Dear Mr. Nasse: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this 2-1day of July, 2015 Encl. 0 • RECEIVED STATE OF ALASKA JUL 1 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION bT5 7/tivfrs APPLICATION FOR SUNDRY APPROVALS AOG 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ 4.;.,f Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 215-015 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20648-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 Blossom#1 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): Fee-Private(Ninilchik Unit Tract 3)/ADL 389737 Ninilchik Field-Beluga/Tyonek 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): 11,198 7,555 11,074 7,439 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 2,495' 10-3/4" 2,495' 1,586' 5,210 psi 2,470 psi Intermediate Production 6,785' 7-5/8" 6,785' 3,406' 6,890 psi 4,790 psi Liner 4,635' 4-1/2" 11,198' 7,555' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4-1/2" 12.6#/L-80 6,563 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer;N/A 6,563'MD/3,197'TVD;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/31/2015 ❑ ❑ WDSPL ❑ Suspended E]Commencing Operations: OIL WINJ 16.Verbal Approval: Date: GAS 2 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 Taylor Nasse Email tnasse(a�hilcorp.com Printed Name Tayl r Nasse Title Operations Engineer Signature , 7--- r ' r —_ Phone 907-777-8354 Date 7/1')// O COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: cT" 3t5- y36 Plug Integrity LiBOP Test E Mechanical Integrity Test ❑ Location Clearance ❑ Other: jS OD ( 5.. ���:t / Baa f CT) Spacing Exception Required? Yes ❑ No 12 Subsequent Form Required: C �& " ' , I APPROVED BY Approved by: �..� COMMISSIONER THE COMMISSION Date: 7 —Zq--/� • ®Rrivep[INicik SubmitForm and Form 10-403 Revised 015 alid for 12 month f m the date of approval. ttach ents in Duplicate 7-22.45- RBDMS AUG - 2 2015 . %�, s:. . ac .4-. • • Well Prognosis Well: Blossom#1 fiilcoru Alaska,LL Date:7/15/2015 Well Name: Blossom#1 API Number: 50-133-20648-00 Current Status: New Grassroots Well Leg: Estimated Start Date: July 31, 2015 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-015 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) AFE Number: 1413217C Estimated Bottom Hole Pressure: —3,199 psi at 7,439' TVD (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,455 psi (0.10 psi/ft gas gradient) Brief Well Summary Blossom #1 is a grass roots well that is currently being completed. The well consists of 10-3/4" surface casing and 7-5/8" production casing with 4-1/2" liner/liner packer and 4-1/2"tie-back tubing. Objective of Work Add perforations in the Tyonek sands. Coiled Tubing Procedure 1. RU CTU and equipment. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 2. PT BOPE to 250 psi low/4,500 psi high. Note that the well is pressurized with nitrogen. 3. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 4. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton MAD Pass log dated July 12th, 2015. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek T28 ± 10,492 ± 10,610 ±118 • Tyonek T50 ± 10,971' ± 10,986' ±15 • 5. POOH. 6. Flow well through test separator and record water and gas rates. 7. If any of the sands are not commercial,then the zone will be plugged back with a bridge plug. 8. RD coiled tubing. 9. Turn well over to production. • • Well Prognosis Well: Blossom#1 Hilcorp Alaska,LL Date: 7/15/2015 Attachment: 1. Proposed Wellbore Schematic 2. CT BOPE Schematic 3. Wellhead Diagram H . . PROPOSED SCHEMATIC Ninilchik Unit Well: Blossom#1 API: 50-133-20648-00• API: 50-133-20648-00 Hileorp Alaska,LLC CASING DETAIL 2 \. Size Type Wt Grade Conn. ID Top Btm 16" r' ;4 16" Conductor 84 X-56 Weld 15.010" Surf 110' '*: ,. 10-3/4" Surf.Csg 45.5 L-80 BTC 9.950" Surf 2,495' + 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 6,785' ,,! ' 3 � , TOC @ 10-3/4 '¢' -` 2,000' 4-1/2" Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,563' 11,198' k TUBING DETAIL .0 if ' 4-1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,563' ,y t ' JEWELRY DETAIL A 4 ' No. Depth ID OD Item II, 5 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" .,� 2 19' 3.958" 4.500" Pup Joint 7-5/8" ` ." 3 ±2,000' 3.813" 6.500" 4-1/2"Chemical Injection Mandrel Shoe @ 6,785' x ,` 4 6,563' 3.958" 4.500" 4-1/2"Seal Assembly RA Mkr Jt ; • 0 Ninilchik Unit COIL BOPE Blossom #1 fll kswp;%h.,La,I.II.: 06/05/2015 Blossom#1 16X10%X75/8X41/ Coil Tubing BOP E Lubricator to injection 1 Laihead rJi 1�, d 1.75"Tandem Stripper I 1 Blind/Sheai=11/16 10 =:Blind/Shear .IuI.11110111 l\ rim iimi 101111Blind/Shear'= =.Blind/Shear I,I.I• - C 0. --_ c_ —— Slip • Slip *IiF 00111 Pipepipe „'•s Mud Cross AIM. 91- �III 3 I 4 1/16 10M X 4 1/16 10M Outlet Mil w/2-2 1/16 10M full opening FMC valves 1 III @ I* 0 li m m i 14 i @ liii Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M ICI (CI2 1/16 10M 2 1/16 10M Crossover spool Ft, Jr- C‘ \cc\ 4 1/16 10M X 4 1/16 5M I `� ' 00�t 6O .. c Valve,Swab,WKM-M, • a\sle�F��� \��N5��da 4 1/16 5M FE, HWO,DD trim is _ 3\2,S �y�� o e�aco� in ■ ip it I. iti-s. 0 Valve, Upper Master "'j; �"' WKM-M,4 1/16 5M FE, t,1-- . HWO,DD trim inimai Valve, Lower Master,WKM-M, et Its �� 4 1/16 5M FE,HWO,DD trim is w`Tw M--111111 Grade Level 0 S Ninilchik Unit Blossom #1 !liken,Alaska.Ili. 06/05/2015 Ninilchik Unit Tubing hanger,SME-CL,11 X 4%2 Blossom#1 EUE lift and susp,w/4"Type H 16 X 10%X 7 5/8 X 4 1/2 BPV profile,2-3/8 CCL,Alloy material BHTA,Otis,4 1/16 5M FE X 6.5"OtisQuick Union Alb •I \14\L ,lam" Ott` ANI\, \�L • Valve,Swab,WKM-M, ... a��e IS\\ -'\ O �1�r,�1 ��a 4 1/16 5M FE, HWO,DD trim (u(o" J ' ' z ,., FE�1 oz'co� '3 J��gtJ` oc . . pJ: 4'. . c, _ r-- Valve,Upper Master WKM-M,4 1/16 5M FE, HWO, DD trim -- .O f.u mmiilk Valve,Lower Master,WKM-M, li •. 4 1/16 5M FE,HWO, DD trim P/Ot Grade Level _ `1,11. Wellhead,SMB-22, '5•11 �, * : 1w' 1.1 1 115MX16A3M,w/ lit 1—'811' =�_+4}. I''' 4-2 1/16 5M SSO r r' '�� ` `` ' up q_ _�J { IIS Starting head,Seaboard, 4 ", 16%3M X 16"SOW,w/ ... .! 1....'.°. 2-2 1/16 5M EFO t i D 6: ..-!.:5,-1.: 1 - I ling I I 16" 10%" 7 5/8" 4 1/2" • 2 IS- 015 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive y G 5 Anchorage, AK 99503 { J Tele: 907 777-8308 IEtl imi, ti,i4.i.LTA Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 07/24/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Blossom 1 9 boxes: Dry Cuttings Transmitted herewith are cuttings from BLOSSOM 1 WELL BOX SAMPLE INTERVAL BLOSSOM 1 BOX 1 OF 9 2510' - 3680' BLOSSOM 1 BOX 2 OF 9 3710' - 4880' BLOSSOM 1 BOX 3 OF 9 4910' - 6350 BLOSSOM 1 BOX 4 OF 9 6380' - 6800' BLOSSOM 1 BOX 5 OF 9 6800' - 8930' BLOSSOM 1 BOX 6 OF 9 8960' - 11210' BLOSSOM 1 BOX 7 OF 9 11240' - 12098' RECEIVED BLOSSOM 1 BOX 8 OF 9 7520' - 9440' BLOSSOM 1 BOX 9 OF 9 9440' - 11200' ,JUL 2 4 2015 AOGCC Please include current contact information if different from above. Please acknowledge receipt by si•ning and returning one copy of this transmittal or FAX to 907 777.8510 Received 8y: WV ' . Date: of 77.1 �e„4"1.. I%',_Y THE STATE Alaska Oil and Gas 4 ®f AConservation Commission ALsKA t lh 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F"A _a, Fax: 907.276.7542 www.aogcc.alaska.gov Taylor Nasse Operations Engineer r5' Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Blossom#1 Sundry Number: 315-401 Dear Mr. Nasse: 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, aetv Cathy . Foerster �`~-- Chair DATED this day of July, 2015 Encl. • • J U N 24 STATE OF ALASKA 0757 iF J IX - ALASKA OIL AND GAS CONSERVATION COMMISSION e. APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development EI 215-015 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20648-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 Blossom#1 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): Fee-Private(Ninilchik Unit Tract 3)/ADL 389737 Ninilchik Field-Beluga/Tyonek 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): 6,795 3,416 6,795 3,416 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 2,495' 10-3/4" 2,495' 1,586' 5,210 psi 2,480 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A; N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 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: 7/7/2015 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS RI 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 Taylor Nasse Email tnasse@hilcorp.com Printed Name Tayl Nasse Title Operations Engineer ( ) Signature Phone 907-777-8354 Date C�f d3 1 'J COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: X15. (40 l Plug Integrity ❑ BOP Test lki Mechanical Integrity Test ❑ Location Clearance ❑ Other: L(SIM !'S L( LP t,�: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0-11 c--7 ((.4..,,:,...j 'di , ) 0APPROVED BY Approved by: )920.t.4.44,—.— COMMISSIONER THE COMMISSION Date:? _�Q�/� 7 g' S� Submit Form and Form 10-403 Revised 5/2015 0 Approved applIca o isald for 1F Copt fr m the date of approval. ttach lents in Duplicate RBDMS JUL - 9 201 i r ii I I V / L 7� -s '7 e, 's Well Well Prognosis Well: Blossom#1 Hilcorp Alaska,LL Date: 6/22/2015 Well Name: Blossom#1 API Number: 50-133-20648-00 Current Status: New Grassroots Well Leg: Estimated Start Date: July 7, 2015 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-015 First Call Engineer: Taylor Nasse (907)777-8354(0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) AFE Number: 1413217C Estimated Bottom Hole Pressure: —3,561 psi at 8,283' ND (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,733 psi (0.10 psi/ft gas gradient) Brief Well Summary Blossom#1 is a grass roots well that is currently being completed. The well consists of 10-3/4" surface casing and 7-5/8" production casing with 4-1/2" liner/liner packer and 4-1/2"tie-back tubing. Objective of Work Add perforations in the Tyonek sands. Coiled Tubing Procedure 1. RU CTU and equipment. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 2. PT BOPE to 250 psi low/4,500 psi high. Note that the well is pressurized with nitrogen. 3. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 4. Perforate the Tyonek sands with 2-7/8" 6 SPF 60 deg phased perf guns.All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton LWD Combo log dated June 17th, 2015. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FTC. '� Tyonek T18 ± 10,413' - ± 10,428' ±15 / Sh1r 1,z Tyonek T28 ± 10,578'- ± 10,705' ±127 5. POOH. 6. Flow well through test separator and record water and gas rates. 7. If any of the sands are not commercial,then the zone will be plugged back with a bridge plug. 8. RD coiled tubing. 9. Turn well over to production. • • Well Prognosis Well: Blossom#1 llilcorp Alaska,LL Date: 6/22/2015 Attachment: 1. Proposed Wellbore Schematic 2. CT BOPE Schematic 3. Wellhead Diagram H . • Ninilchik Unit Well: Blossom#1 . HPROPOSED SCHEMATIC 15 APD 50-133-20648-00 Hi!cora Alaska,LLI: CASING DETAIL y 1 44" Size Type Wt Grade Conn. ID Top Btm 16 � irk 16" Conductor 84 X-56 Weld 15.010" Surf 110' ,.. 10-3/4" Surf.Csg 45.5 L-80 BTC 9.950" Surf 2,495' v`4 r 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 6,795' �._� 3 :,�r, TOC @ 10-3/444* 'tor'-)el ` 2,000' 4-1/2" Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,600' 11,915' TUBING DETAIL ' 4-1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,600' 2, JEWELRY DETAIL �," No. Depth ID OD Item 4 " 5 ,. 61. 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" 6 2 19' 3.958" 4.500" Pup Joint 7-5/8" "' ` : 4 1/2"Chemical Injection Mandrel �-: � 3 ±2,000' 3.813" 6.500" 1 Shoe @ 6,795' • 4 ±6,600' 3.958" 4.500" 4-1/2"Seal Assembly A Mkr Jt 7,000' 5 ±6,600' 4.500" 6.500" Liner Tie-Back Receptacle pp__� ; 6 ±6,600' 5.000" 6.672" Liner Top Packer 4^' Y i A Mkr Jt 7,500' t ;�` A Mkr Jt 8,000' PERFORATION DETAIL k ' Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status '41„ "r ,i,•440, T18 ±10,413 ±10,428 ±6,818 ±6,832 2-7/8" Proposed A Mkr Jt 8,500' 0' a° T28 ±10,578 ±10,705 ±6,973 ±7,092 2-7/8" Proposed oi`it : ix"° A Mkr Jt 9,000' : � �, rpt" 4411 a/?, 1`f ;F 3`'■ 4 .r' yT18 Ir . ',.:..r T28 4..„,#)!;"M d f "q 4t,� 6-3/4"hole *444 .' Shoe @ 11,915' PBTD=11,800'MD/8,174'TVD •TD=11,915'MD/8,283'TVD Max Deviation:75 deg Max Dogleg:4 deg/100 Downhole Proposed Updated by TWN 6/22/15 • • Ninilchik Unit . IICOIL BOPE Blossom #1 06/05/2015 nar.'.p %l k.1.1.I t. Blossom#1 16 X 10 Y.X75/8X4%Z Coil Tubing BOP f Lubricator to injection head 0 d I In) 1.75"Tandem Stripper 1 f l �-1 1/16 10 -� 0110 Blind/Shear _ _ Blind/Shear _— _1 01110Blind/Shear =a Blind/Shear =j. 1.311 mem r_-_-—_ Slip =_ Slip 0114 0.1101 :El �� / Mud Cross Pipe = _: Pipe , - [\ 4 1/16 10M X 4 1/16 10M _ Outlet w/2-2 1/16 10M full opening FMC valves n ilii 8 Oil B li mill= I CO II 8 Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M U 2 1/16 10M 2 1/16 10M Crossover spool t>'I 0-0' \,c<, 4 1/16 10M X 4 1/16 5M I 34\L 90 0' v0' �u 3o"ca `�o �JG �,d0 Valve,Swab,WKM M, • NW CPI\FE? \Je��`ti`a5 t 4 1/16 5M FE, HWO,DD trim Do g3 �a �, to 09 .19- 31� 2,S ode ../1.= 3ti� I ; . I I ■ C' i i ► I 1 - - - NI Valve, Upper Master MI ji'r" WKM-M,4 1/16 5M FE, ►1 � HWO,DD trim �• 11111. . Valve, Lower Master,WKM-M, �•. � 4 1/16 5M FE, HWO,DD trim'' 1U1I� 11_il Grade Level 0 0 Ninilchik Unit . iiBlossom #1 06/05/2015 IIIc.,,.i, ti,,.k.,.1,1.1. Ninilchik Unit Tubing hanger,SME-CL,11 X 4'2 Blossom#1 EUE lift and susp,w/4"Type H 16 X 10%X7 5/8 X 4 1/2 BPV profile,2-3/8 CCL,Alloy material BHTA,Otis,4 1/16 5M FE X 6.5"Otis Quick Union WIe�•���',140,O ���,���dta Valve,Swab,WKM M, ,. '.l„,4‘.., �F�' e�` ��1�t 4 1/16 5M FE,HWO,DD trim 0,,•(.11,* 4 31\$� .l$��F.Ope�a�° V iL'' a 1 Valve,Upper Master W WKM-M,4 1/16 5M FE, HWO,DD trim � ! �• J Valve,Lower Master,WKM-M, til'.� 4 1/16 5M FE,HWO,DD trim ,"*.;,/, �"`V Grade Level 21 tr Multibowl Wellhead,SMB-22, 11 w 115MX16%3M,w/ rter � OM! 1111 i,.j. 4-2 16 5M SSO ti: —,�• - 4' '�I u II111.10i I lig.i. It. , , r in head,Seaboard, .� �� Starting _,•,��,, r�1� 16%3M X 16”SOW,w/ -•ira.,_a � nilmn- 2-2 1/16 5M EFO : Ili 1 II 16" 10%" 7 5/8" 4%" AIME= ti OF T4 • �wA\`\I%'� s THE STATE • Alasa Oil and Gas Ftt, of /\ Conservation Commission LsKA _ _ „=„4„ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *,h Main: 907.279.1433 OFALASY'P' Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers �} �, C F Drilling Engineer <T� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Blossom#1 Sundry Number: 315-391 Dear Mr. Myers: 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, (21 Cathy VFoerster �/ Chair DATED this 3fJ'"clay of June, 2015 Encl. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 6) '3 0 i.L S APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program EPlug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other IEj ,Jb,iu Sry14 ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. /41/74 Hilcorp Alaska, LLC Exploratory ❑ Development 0 - 215-015 - 3.Address: Stratigraphic iii Service El6.API Number. 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 50-133-20648-00-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 - Blossom#1 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10. Field/Pool(s): Fee-Private ADL 389737 - Ninilchik Field-Beluga/Tyonek 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): 12,098' 8,409' 11,485' 7,831' None Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 78' 78' N/A N/A Surface 2,495' 10-3/4" 2,495' 1,585' 5210 psi 2470 psi Intermediate 6,785' 7-5/8" 6,785' 3,406' 6890 psi 4790 psi • Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD(ft)and TVD(ft): N/A 12.Attachments: Description Summary of Proposal ✓❑ 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: Operations: 6/22/2015 CommencingOIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 6/22/2015 GAS E WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Guy Schwartz GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Monty Myers Email mmyers c(D.hilcorp.com Printed Name Monty Myers Title Drilling Engineer Signature --.%— ' Phone 777-8431 Date 6/22/2015 COMMISSION USE ONLY Conditions of approval: Notify Commissions representative may witness Sundry Number: Plug Integrity ❑ BOP Test Vrr. Mechanical Integrity Test ❑ Location Clearance ❑ Other: `-1 c , f ave ` 5 ,- ( MA-S-1° 2 7 S 3 ) Spacing Exception Required? Yes ❑ No Et !Subsequent Form Required: U -Y 0 Edi L"e/era-) APPROVED BY Approved by:al-67 p COMMISSION0 E I SI N Date: / _ 30�< G 3C'f RJ Form 10-403 Revised 5/201 Approved application is valid for 12 monthsom the at f a al. Attachme is in Duplicate RBDMS\ JUL - 1 2015 .- .S,S ' `3 'S • Monty Myers . Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Alaska,1,LE June 22nd, 2015 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Blossom#1 10-403 Dear Commissioner, Enclosed for review and approval is a 10-403 "Abandonment of BHA and Change to Procedure" for the latest plan to complete Blossom#1. While drilling the production hole on Blossom#1 @ 12,098' MD, the stringed torqued up and the BHA subsequently became stuck while attempting to backream out of the hole with the directional/LWD assy. Bottom of the fish is located at—12,089', TOF is located at—11,500' MD. 5 days were spent trying to free the BHA, but efforts have been unsuccessful. - The directional/LWD assembly consists of: 6-3/4" PDC bit, mud motor, Float sub, stabilizer, MWD collar, Dual gamma ray collar, resistivity collar, Den/Neu collars(with nuclear source), PWD collar (2) non mag flex collars, (4)jts HWDP,jar, (1)jt HWDP. Hilcorp is prepared to abandon further attempts at BHA recovery; and Plug/complete the well as detailed below. There is some encouraging gas pay which exists in the (Upper/Middle Tyonek)that Hilcorp would like to make attempts at producing. 1. Sever drill pipe at 11,500'with coil tubing unit. 2. TOH w/coil. 3. POOH with drill pipe from 11,500'. 4. M/U 6-3/4"clean out BHA and clean out wellbore to TOF at 11,500' MD. 5. Run 4-1/2" liner with 200' shoe track to TOF(nuclear source at 12,000'). 6. Conduct primary cmt job with 15.2 ppg slurry to LTP. 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 • • Hilcorp Alaska , LLC Blossom #1 Sidetrack Program Ninilchik Field Revision 0 June 29th, 2015 • • Blossom #1 Drilling Procedure llikrorji Alas&a,III' Contents 1.0 Planned Wellbore Schematic 2 2.0 BHA left in the hole 3 3.0 Wellbore Preparation 4 4.0 Drill 6-3/4"Hole Section 6 5.0 Run 4-1/2"Production Liner 10 6.0 Cement 4-1/2"Production Liner 13 7.0 Wellbore Clean Up&Displacement 17 8.0 Production Tubing Installation and Perf. 18 9.0 Anticipated Drilling Hazards 19 • • Blossom#1 Sidetrack Procedure HilrorI i A IA kA,t.i.t. 2.0 BHA left in the hole COMPONENT DATA t � �� ,,�,�� � " ��'' �'''44,l�l�rr�et ,3+'1�b " ID� a � { "�t�1 c��r `� tulalt El Varee V613PDUX 4007565 5.000 t500 6.750 60.89 P 3-112"REG 0.80 0.80 El 5'SpenyDrill Lobe 6/7-6.0 stg 500-022 5.000 3.120 INN 48.00 B NC 38 © 4-314"Float Sub 11442494 4.680 2.250 45.07 B 3-1/2"IF 2.15 26.33 MI 43/4"DM Collar 11521020 4.740 2.610 ® 47.00 LIMEM 9.19 MEM Q 4 314"Gamma Collar 11578398 4.750 2.610 47.00 B 3-1/2"IF 9.27 44.79 MI 43/4"ADR Collar 90440111 4.750 1.250 MN 53.7027.10 MODEM © 4 3/4"ALD Collar 90440405 4.750 1.250 5.570 45.50 B 3-1/2"IF 14.27 86.16 m stabilizer 5.570 Li 4 314"CTN Collar 90440505 4.750 1.250 50.50 laleia 11.02 97.18 0 4 314"PWD 90439185 4.730 1.250 47.90 9.22 106.40 10 43/4'TM Collar 11644596 4.700 onion 46.10 ® 4-314'NM Flex Collar 11321311 4.640 2.250 44.08 B 3-1/2"IF 30.68 148.34 m 4-314'NM Flex Collar 11623882 4.770 2.250 MEI LEIM 31.09 179.43 ® X-Over 3 112"IF Pin x CDS-4D Box Rig 5.250 2.688 54.44 B 4.5 CDS-40 1.58 181.01 m 6 its 4-112"HWDP CDS-40 ® 4.500 Ei3E1 36.86Mil184.36 MBE NM X-Over CDS-40 Pin x HT-38 Box 4370 5.260 2.125 61.97 B 4'HT 38 1.09 366.46 ICE 4-3/4"Weatherford Jar 1400-1178 1.875 ® 54.59 28.43 394.89 X-Over HT-38 Pin x CDS-40 Box 4363 5.260 2.000 63.35 B 4.5"CDS-40 1.04 395.93 11131 7 its 4-112"HWDP CDS-40 O 4.500 Ecumg 36.86 MEM 215.20 MEE Total - 611.13 Page 3 Revision 1 June, 2015 • • Blossom #1 II Sidetrack Procedure Hiirorp AlaA a,1,id' 1.0 Planned Wellbore Schematic 1,,,, hk U' t II Well: l`5iopnmr F2 'OD Planned SCHEMATIC 'OE 215-5lca t,..,. CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" ..q, al , 16" Conductor 84 X-56 Weld 15.010" Surf 78' 10-3/4" Surf.Csg 45.5 1-80 BTC 9.950" Surf 2,495' 'OC @ 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 6,785' 10-3/41'; 2,000' 4-1/2" Prod Liner 12.6 1-80 D HT 3.958" 6,585' 11,932' r' TUBING DETAIL 4-1/2" Tubing 12.6 L-80 BT 3.958" Surf 6,585' JEWELRY DETAIL No. Depth ID CD Item 1 18' 4.00" - Tubing Hanger,4-1/2 4. 2 19' - Pup Joint 3 -6,425' 4-1/2"Chemical Injection Mandrel 4 -6,485' 7-5/8"x 4-1/2"Retrievable Production Packer 5 -6,535' 4-1/2"X-Nipple 6 ~6,585' 4-1/2"Tailpipe **Jewelry set depths will be finalized after reviewing the open hole logs** 6 . Tie Back Receptacle Liner Hanger Packer @ 6,585' -51- k. Shoe @ 6,785' 41 tor iy05 O Fish details: 6-3/4"hole 6-3."4"PDC bit mud motor,Float sub,stabilizer, MEND collar.Dual gamma ray collar,resistivity collar, Dent'eu collars(with nuclear source),Pressure while drilling collar,(2)non mag flex collars,(6)its HWDP, jar.X0.H11DP,DP.Neutron Source at-12,000'MD. ', IMF at.1,805'MD 4 LBOF at 12,495'MD V 1 t _70PBTD 11,740 DJ New proposed@ 8,063'TVD /8,410'TVD .,_ . Fish TD=12,098'MD/8,409'TVD Page 2 Revision 1 June,2015 • • Blossom#1 Sidetrack Procedure Hiles rp Alamka,1.LC 3.0 Wellbore Preparation Blossom#1 is an exploratory Tyonek and Beluga well. Primary objectives are Upper Beluga through Beluga 60 reservoir sandstones. While drilling the production hole at 12,098' the driller noticed the on bottom torque quickly increasing. He attempted to PU and backream through the spot but immediately became stuck. We made numerous attempts to free the pipe, but have been unsuccessful in severing or jarring the pipe free. We were able to finally cut the drill pipe with a radial cutting torch at 7,805' and get released from the BHA. Additional attempts to jar at this depth and sever at 10,505' were both unsuccessful. The plan forward is to spot a 500' cement plug on top of the BHA left in hole at 7,805' and re-drill the production hole. 3.1 Release from fish at 7,805'. 3.2 POOH, LD fishing BHA 3.3 PU 2-7/8" cement stinger with 800' of tubing and TIH to top of fish at—7,805' 3.4 Circulate and condition mud and clear rig floor. 3.5 RU Schlumberger cement unit and hard lines and pressure test to 4500 psi. 3.6 Blend and pump as per Schlumberger balanced cement plug CemCade. 3.7 Total displacement is 104.2 bbls,pump no more than 99 bbls for displacement, leaving 5 bbls of cement inside pipe for balancing. Cementing:Balanced Plug Calculator NOTE:WSI=Work String In,WSO=Work String Out Do Calculation Reset I Plug Top Depth(ft WSO):17305.00 Spacer Top(ft WSO):J7041.94 Plug Bottom Depth(ft WSO): 7805.00 Top of Cement(ft WSI):17278.33 Plug Volume(ft3): 124.252 Spacer Volume Behind(bbl):11.64327 Plug Volume Excess(410. Displacement Volume(bbl):199,5529 Spacer Volume Ahead(bbl): 10.00 Displacement Depth(ft WSI): 7000.93 CasingData Open Hole Data Workstrin Data R 9 ID[in) Depth(ft) - ID(in) Depth(ft) OD[in) ID[in) Depth(ft) 6.875 6785.00; 6.75 7805.00 7 4.50 3.826 7005.00 0 0 - 0 0 ► 2.875 2.441 7805.00 Page 4 Revision 1 June, 2015 • Blossom #1 Sidetrack Procedure HilrorI p Alaska>LLf: Section: Calculation: Vol(BBLS) Vol(ft3) 6-3/4" OH : 500' x 0.04426= 22.13 124.25 Total Volume: 22.13 bbls 124.25 ft3 3.8 POOH slowly to allow cement to balance 3.9 Pull up hole 4 stands above TOC plug to approximately 7,060'. Circulate and condition mud for 2X bottoms up and ensure no cement is left inside pipe. 3.10 RD Schlumberger cement unit and hard lines. 3.11 POOH with cement stinger. LD BHA and WOC minimum 24 hours. Page 5 Revision 1 June, 2015 Blossom#1 Sidetrack Procedure flifrorp AlaNka,IAA 4.0 Drill 6-3/4" Hole Section 4.1 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 pipe shed. 4.2 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 4.3 Ensure TF offset is measured accurately and entered correctly into the MWD software. 4.4 Confirm that the bit is dressed with a TFA of 0.46 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. 4.5 NO LWD will be run in 6-3/4" hole section only GR/RES: • Gamma Ray(DGR: Combined Gamma Ray) • Resistivity(EWR: Shallow/Med/Deep) 4.6 P/U 6-3/4"directional drilling assy: Page 6 Revision 1 June,2015 • • Blossom #1 Sidetrack Procedure Hilrm.p Alurka,1.11 4.7 Primary bit will be the Security EM65D: 6-3/4" (171mm) EM65D PRODtICI SPECIFICATIONS ('utter Type X3-Extreme!billing `i.` Body Type MATRIX i '. Total('utter(-Hunt 73 lir 440 A,Cutlet Distribution 11,,llki 1ligra - 4Nil ti„4" Puce 13 ii (-mop a I I 0 t , Up[bill 5 C A Nucr of Nozzles 41 tnla :i Number of Medium Nozzles 0 iN Number of Small Nozzles fi • IR Y IN: . Number of Micro NtwkNozzles U Number of Darts(Stade) 11 o Numhcro!'Replaceable Foos ISizrl U Junk Slut Area i s4 ut) 8•6s Normalized[arc Volume 34.61Pli t a API Connection 3-112 REG PIN kt° Recuenntktasled Make-Up lmime' 5.173-7,6,15 FNlbs. Nominal Dimensions** Make-Up Face to Nosc 9.42 in-239 rate) t taupe I-enpth 2 in-31linen Sleeve Length ti in-Q men Shaul.Diameter 4.5 in-114 Hurt [utak Out Plate iblai. 'Iegacpit► i$14.151'44024 Approximate Shipping Wcipht #((Lbs. 4114. SPECIA{.FEATURES Up-Drill{'utters on Gage Pads,I'16"Stepp®d Gage,.Optimized Dual Row-'D"Feature Material#761302 •Hit tpccific nVanpm10141rd mek.-,p torque is t litnalk'an of Oh bit I D.and aetiaatt hit sage CS.D.utilixtd is sprcifsad in 11'1 RPV J Secure A.*2. **Ucs,an dantenst.iim are ttoomedt and uaag cttr, slightly on nanufuswrnd ptwavt.}InitilfarRtn Ural)iib.and,Services rtootcts me imntunuu ll nater ed uaut of nae PAtiluet suet.'t,ani.r.Prat[.chimp.'a ittY,mi notice -.2413 Halliburton.All rights reserved Sale,of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Haltiburmu and the customer that is applicable to the sale. www haliiburic>n.cc m Page 7 Revision 1 June,2015 • • Blossom #1 Sidetrack Procedure Hilrorp Alaska,LLC 4.8 TIH to TOC. Wash down last 2 stands to prevent running in to green cement and plugging BHA. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. 4.9 Wash down until cement is hard enough to stack 50k lbs. of weight on. 4.10 Time drill of the low side of the hole for: • 1 foot per hour for 5' • 2 feet per hour for 5' • 5 feet per hour for 5' • 10 feet per hour for 5' 4.11 Or until mud loggers determine that our cuttings are 100% new formation. 4.12 Once we have confirmed we have a new hole started, drill as per new Blossom 1 wp#6 and normal drilling practices to TD. 4.13 6-3/4" hole section mud program summary: Weighting material to be used for the production hole section will be calcium carbonate. Additional weighting agent 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, Tool pusher office, and mud loggers office. System Type: 9.2 ppg 6%KC1/EZ MUD/BDF-499 fresh water based drilling fluid. Properties: Mud Plastic MDWeig t Viscosity Viscosity Yield Point pH HPHT 7,300'- 11,932' 9.2—9.4 40-53 15-25 15-25 8.5-9.5 < 10.0 Page 8 Revision 1 June,2015 • 1111 Blossom#1 11 Sidetrack Procedure Hikorp Alaska.Ll.f System Formulation: 6% KCL/EZ MUD/BDF-499 Product Concentration Water 0.905 bbl KCI 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 ppb DEXTRID LT 1-2 ppb PAC-L I ppb BARACARB 5/25/50 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.2—9.6 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 4.14 Drill 6-3/4" hole to 11,932' MD /8,410' TVD MD using above motor assembly. • Use good drilling practice for drilling breaks. i.e. PU and circulate • Time drill the coal to reduce our risk of getting stuck. • Monitor magnetic interference from lost BHA and have DD adjust accordingly • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss< 6. • Take MWD surveys every stand drilled. • Mud Loggers: 30 ft samples with 20' samples in zones of interest, two sets of cuttings, chromatograph,pixler plots. 4.15 Hilcorp Geologists will follow GR/RES closely to determine exact TD. 4.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 4.17 TOH with drilling assy, handle BHA as appropriate. Drop drift on trip out. Page 9 Revision 1 June,2015 410 Blossom #1 Sidetrack Procedure Hilrorp Alaska,l.l.f. 5.0 Run 4-1/2" Production Liner 5.1 M/U and rack cement stand in derrick. • Ensure to drift components prior to M/U. Ensure dart will pass through components. • Confirm largest OD of packer assy will pass through wear bushing. 5.2 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 on the deck prior to running. • Be sure to count the total#of joints on the deck 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. 5.3 P/U shoe joint, visually verify no debris inside joint. 5.4 Continue M/U &thread locking shoe track assy consisting of • (1) Shoe joint w/shoe bucked on&thread locked(coupling also thread locked). • (1) Joint with float collar bucked on pin end&thread locked(coupling also thread locked). • (1) Joint with landing collar bucked on. • Solid body centralizers will be pre-installed on shoe joint &FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 5.5 Continue running 4-1/2"prod liner • 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 to 7,500' MD. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 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 Page 10 Revision 1 June,2015 • • Blossom #1 Sidetrack Procedure H&iioril AiA4 a.Lt.t� Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-1/2 in 12.60 lb/ft(0.271 in) L-80 standard Material L80 Grade 80,000 Minimum Yield Strength(psi) 1111111MMIMINIFUSA 95,000 Minimum Ultimate Strength(psi) varJt USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77041 Phoe-713-479-3200 4.500 Nominal Pipe Body Q.D.(in) Fax:713-479-3234 3.958 Nominal Pipe Body LD.(in) E-mail=v CINT' 0.271 Nominal Wall Thickness(in) 12.60 Nominal Weight(lbs/ft) 12.25 Plain End Weight(lbs./ft) 3.600 Nominal Pipe Body Area(sq in) Pipe Body Performance Properties 288,000 Minimum Pipe Body Yield Strength(lbs) a 7,500 Minimum Collapse Pressure(psi) 8,430 Minimum Internal Yield Pressure(psi) 7,700 Hydrostatic Test Pressure(psi) Connection Dimensions 5.000 Connection Q.D.(in) 3.958 Connection ID.(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 DesignFactor 314,000 API Joint Strength(lbs) 283,000 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) 5.6 Ensure to run enough liner to provide for approx. 200' overlap inside 7-5/8" casing. Ensure hanger/pkr will not be set in a 7-5/8" connection. Page 11 Revision 1 June,2015 • • Blossom #1 Sidetrack Procedure HiIvorp Alawka,LLC 5.7 Before picking up Baker ZXP liner hanger/packer assy, count the#of joints on the pipe deck to make sure it coincides with the pipe tally. 5.8 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 5.9 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 5.10 RIH w/liner on DP no faster than 1-1/2 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 5.11 M/U top drive and fill pipe while lowering string every 10 stands. 5.12 Slow in and out of slips. 5.13 Circulate 1-1/2 drill pipe and liner volume at 7-5/8" shoe prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. Nominal liner hanger setting pressure is 2500 psi. 60% of this value is 1500 psi 5.14 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 5.15 Continue to fill the DP every stand down using fill up line on rig floor. Do not stop to fill casing. 5.16 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 5.17 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure (1500 psi). Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 5.18 Reciprocate&rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 12 Revision 1 June, 2015 • • Blossom#1 Sidetrack Procedure Holeorp.4laRka,1.1A 6.0 Cement 4-1/2" Production Liner 6.1 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. • 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. 6.2 Attempt to rotate&reciprocate the liner during cmt operations. This is the most effective method to ensure effective mud and wall cake removal and a good quality cmt bond. 6.3 Pump 5 bbls 10 ppg MUDPUSH II spacer. 6.4 Test surface cmt lines to 4500 psi. 6.5 Pump remaining 15 bbls 12 ppg MUDPUSH II spacer. 6.6 Mix and pump 15.3 ppg class"G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess. Section: Calculation: Vol(BBLS) Vol(ft3) 7-5/8" x 4-1/2 DP" 200' x 0.026 = 5.2 29 Overlap: 7-5/8" x 4-1/2"Liner 200' x 0.026 = 5.2 29 Overlap: 6-3/4" OH x 4-1/2" Liner: (11,932—6,675')x 0.025 x 1.5 = 197 1106 Shoe Track: 200' x 0.019 = 3.8 21 Total Volume: 211.2 bbls 1185 ft3 Page 13 Revision 1 June, 2015 • • Blossom #1 Sidetrack Procedure Hilrorp Alaska, Tail Slurry System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk Mix Fluid 5.879 gal/sk Base Fluid 5.879 gal/sk Expected 70 Bc at 5:00 hrs Thickening Code Description Concentration G Cement 941b/sk D046 Antifoam 0.2%BWOC D202 Dispersant 1.5%BWOC Additives D400 Gas Control 0.8%BWOC D154 Extender 8.0%BWOC 6.7 Drop DP dart and displace with 9.2 ppg drilling fluid. 6.8 Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 6.9 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 6.10 Bump the plug and pressure up as required by Baker procedure to set the liner hanger(20% above nominal setting pressure. 2500 psi is nominal setting pressure. Pressure up to 3000 psi to confirm hanger setting. 6.11 Slack off total liner weight plus 20k to confirm hanger set. 6.12 Do not overdisplace by more than''/2 shoe track. Shoe track volume is 1.7 bbls. 6.13 Pressure up to 4200 psi to release the running tool(HRD-E) from the liner. 6.14 Bleed pressure to zero to check float equipment. Page 14 Revision 1 June,2015 • I Blossom#1 Sidetrack Procedure I Hileor p Alaaka LLC 6.15 P/U, verifysetting tool is released, and expose setting dogs on top of tieback sleeve. 6.16 Rotate slowly and slack off 50k downhole to set the ZXPN liner top packer. 6.17 P/U to P/U weight plus 1 ft. 6.18 Close annular and test 4-1/2" DP x 7-5/8"annulus to 1500 psi/ 10 min to test liner top packer. 6.19 Bleed off pressure, open up annular. 6.20 Pressure up to 500 psi down DP and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops off rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 6.21 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 6.22 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 6.23 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 6.24 POOH, verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 6.25 If the HRD-E tool still does not release hydraulically, left-hand(counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 6.26 NOTE: Some hole conditions may require movement of the drillpipe to "work"the torque down to the setting tool. 6.27 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet forgers. Pick straight up with workstring to release collet from the profile. Page 15 Revision 1 June, 2015 • • Blossom#1 Sidetrack Procedure Hilcorp Alas1 H,1A1 Ensure to following o the report on wellez: P • 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 and cdinQerAhilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 16 Revision 1 June,2015 • I Blossom#1 Sidetrack Procedure Hilrorp.AIa$ka,lit 7.0 Wellbore Clean Up & Displacement 7.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 3.75"bit or mill. • Casing scraper for 4-1/2" 12.6# casing. • +/- 4600' 2-7/8" workstring. • Crossover(No PBR Polish Mills). • Casing scraper for 7-5/8" 29.7# casing. • 4-1/2" DP to surface. 7.2 TIH &clean out well to landing collar (+/- 11,800' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 3-3/4"bit is worked down to the landing collar. • Space out the cleanout BHA so that the 4"bit reaches the 5" landing collar when crossover is +/- 30' above the 5" liner top. • The primary objective of the clean out run is to ensure the TCP assy will reach intended depth. 7.3 After wellbore has been cleaned out satisfactorily using mud, test casing to 3500 psi/ 30 min. 7.4 Displace drilling fluid in wellbore with a hi-vis pill followed by fresh water. • Consider catching drilling fluid in rain-for-rent tanks for use on a future well if feasible. • Circulate fresh water into wellbore until clean-up is satisfactory. Do not recirculate fluid, • After a couple circulations using FW, short trip the assy to bring the upper 7-5/8" scraper to surface. • RIH again&tag landing collar w/4"bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by 6% filtered KC1(or alternative fluid specified by Ops team). 7.5 TOH w/clean out assy. LDDP on the trip out. Note any abnormal wear on the clean out assy. Page 17 Revision 1 June,2015 • • Blossom #1 Sidetrack Procedure Hilrorp Alaska,ILIA: 8.0 Production Tubing Installation and Perf. 8.1 A separate Sundry will be submitted to the AOGCC that will cover the post well logging program/production tubing installation/perforation procedure. Page 18 Revision 1 June,2015 • • Blossom#1 Sidetrack Procedure Ifileorp Alakka.IAA 9.0 Anticipated Drilling Hazards 6-3/4" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, &750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 &20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. 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 1 ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 6 m1/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 6% KC1 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. • Do not use "black products"to stabilize coal sections. • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 19 Revision 1 June,2015 • • Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday,June 29, 2015 4:45 PM To: Schwartz,Guy L(DOA);Cody Dinger- (C); Davies,Stephen F(DOA) Cc: Shane Hauck;Shane Barber- (C); Doug Yessak- (C); Rance Pederson - (C) Subject: RE:Sidetracking Blossom#1 (PTD 215-015) Attachments: Blossom#1 Sidetrack Program (revl).pdf Guy, I'm waiting to get the finalized directional plan, but this has the basic information I think you need.As soon as get the directional plan I will forward to you. Abandonment/kick of plug spotted from 7805'to 7305'. Our current sidetrack plan has us kicking off at 7305' but that may change slightly depending on where we finally get kicked off. We will be sure to leave at least 200'of cement on top of the fish. 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: Monday,June 29, 2015 10:03 AM To: Monty Myers; Cody Dinger- (C); Davies, Stephen F(DOA) Subject: RE: Sidetracking Blossom #1 (PTD 215-015) Monty, You do not need a revised 10-401 as long as you stay within 500 ft of the original well plan. The abandoned hole will become Blossom 1 PB1. It will take an API -70 suffix. I will need an updated procedure and schematic for the abandon BHA sundry(#315-391) . You may forward that to me by email and I will update the sundry we have here. Regards, 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 1 S recipient of this e-mail,please delete it,Wout 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@hilcorD.com] Sent: Monday,June 29, 2015 9:53 AM To: Schwartz, Guy L(DOA); Cody Dinger- (C); Davies, Stephen F(DOA) Subject: Sidetracking Blossom #1 Guys, After several failed attempts to free the fish or even remove some more of the BHA that was left in the hole,we have decided to cut our losses and move forward with sidetracking the well. The plan will be to spot a 500'cement plug on top of our fish(7805'),then kick off low side and try to twin the well. Approximate kick off depth will be 7300'.We would like to TD the well as close as possible to the original BHL pending what kind of magnetic interference we see.We plan on drilling with a stripped down BHA consisting of only MWD/GR/RES.We will probably need to mad pass after we reach TD with LWD. I am working on the new directional plan now to send to you,and I have Halliburton checking with the NRC to make sure this abandonment plan works for them also. What do you need from us?A revised 10-401? Thanks! Monty M Myers Drilling Engineer Hilcorp Alaska Office:907.777.8431 Cell:907.538.1168 2 • • Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday,June 25, 2015 6:58 AM To: Schwartz, Guy L(DOA) / Zi c—O( Subject: FW: [EXTERNAL] Blossom#1 Abandonment Program In the thread of email below is an approval statement from Steve Woods at the NRC, approving our plan to run liner to the TOF and cement, when we get to that point. For your records as well. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Doug Griffin [ ailto:Doug.GriffinHalliburton.com] Sent: Tuesday, June 23, 2015 4:45 PM To: Monty Myers Subject: RE: [EXTERNAL] Blossom #1 Abandonment Program No attachment.This email from Steve Woods is sufficient for your records. Doug Griffin Sperry Drilling LWD Coordinator-Alaska Halliburton 6900 Arctic Blvd Anchorage AK 99518 Office-907-273-3567 Cell -907-267-9463 Our Vision -To be THE Trusted Drilling Solutions Advisor Our Mission -We engineer solutions to drill safe, faster and on target every time to maximize reservoir value From: Monty Myers [mailto:mmyersOhilcorp.com] Sent: Tuesday, June 23, 2015 4:34 PM To: Doug Griffin Subject: RE: [EXTERNAL] Blossom #1 Abandonment Program Is there supposed to be an attachment? Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 1 • • From: Doty Griffin [mailto:Doug.Griffin@)Halliburton.com] Sent: Tuesday, June 23, 2015 4:26 PM To: Monty Myers Subject: FW: [EXTERNAL] Blossom #1 Abandonment Program Monty, Here is the approval from the NRC. Let me know when you get CIP as the NRC would like to be notified. Doug Griffin Sperry Drilling LWD Coordinator-Alaska Halliburton 6900 Arctic Blvd Anchorage AK 99518 Office-907-273-3567 Cell-907-267-9463 Our Vision -To be THE Trusted Drilling Solutions Advisor Our Mission -We engineer solutions to drill safe, faster and on target every time to maximize reservoir value From: Steve Woods - Global RSO Sent: Tuesday, June 23, 2015 5:48 AM To: Doug Griffin; Brian Stephens Cc: Jill Mead Subject: RE: [EXTERNAL] Blossom #1 Abandonment Program Doug/Brian Spoke with Rick Munoz of the NRC Region IV office at approximately 8:30am on June 23, 2015 and he approved the abandonment plan which Doug indicated there would be 200 feet of cement on the drill string above the sources then the shoe. Steve Woods Global Radiation & Explosive Safety Senior Radiation Safety Officer Halliburton Energy Services, Inc. Office:580-251-3936 Mobile:580-618-0791 e-mail: Steve.Woods(c�Halliburton.com From: Doug Griffin Sent: Monday, June 22, 2015 4:16 PM To: Jill Mead; Steve Woods - Global RSO; Brian Stephens Subject: Fwd: [EXTERNAL] Blossom #1 Abandonment Program All, What I did not understand until now is that Hilcorp will have a 200' shoe track tail. So basically the liner will be set at the fish but they will have 200' of cement up inside the liner thus isolating the zone. 2 • 111 315 Mix and pump cmt per below recipe_ Ensure cmt is pumped at designed weight. Job is designee to pump 100°0 OH excess_ Section: Calculation: Vol Vol (ft3) (BBL S) 7-518" x 4-1/2" DP Overlap: 200' x 0.026= 5.2 29.2 7-5/8" x 4-1/2" liner Overlap: 200 x .026= 5.2 29.2 6-3/4" OH x 4-1/2" Liner (11.500—6,785) x 0.025 x1.5 = 177 994 Shoe Track(Tail): 200' x 0.015 ---� 3 17 Total Volume (Tail): 190.4 1069.4 .:,,. '4` 6-314"hole oft: , `4.', a4 t 1.: 14' ;R a4,,.. •. , 4-1/2"Shoe to 11,540' Fish details: 101 6-3 4"PDC bit.mud motor.float sub.stabilizer. MWD collar. Dual gamma ray collar.resistivity collar. ' I Dens collars(with nuclear source)_ Pressure vtale 9 : C.11ar 2 nonmag flet collars.(6)jt,#HWDP, allIms TOP at 11,500`MD PBTD "11,300' ' 7,750'TVD • 'O/6,409'ND Here is the initial abandonment plan. They have stopped fishing operations and plan cement the fish in the hole. It will take several days before they get to the point where they can pump cement so we will have time on Monday to get NRC approval. One engineer will stay on location for the next few days until cement is set. Sent from Outlook Forwarded message From: "Luke Keller" <lkeller@hilcorp.com> Date: Fri,Jun 19, 2015 at 4:21 PM-0700 Subject: [EXTERNAL] Blossom#1 Abandonment Program To: "Monty Myers" <mmyers@hilcorp.com>, "Paul Mazzolini" <pmaz7olini@hilcorp.com>, "Cody Dinger- (C)" <cdinger@hilcorp.com> Cc: "Doug Griffin" <Doug.Griffin@Halliburton.com> All, Attached is a first pass at an abandonment program to accompany the 10-403 for BHA abandonment. 3 • • ti OF Taj I//7%sem THE STATE Alaska Oil and Gas tib, of Conservati®n Commission } LAsKAL 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer 5 Q ,S Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Blossom#1 Sundry Number: 315-354 Dear Mr. Porhola: 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, .�j Daniel T. Seamount, Jr. Commissioner Lt‘ DATED this 1 2 day of June, 2015 Encl. • • REC WED STATE OF ALASKA JUN 0 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION V___, 0iz.li--, APPLICATION FOR SUNDRY APPROVALS nr` % 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Run Tubing;Coil N2❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development El 215-015 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic [11 Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20648-00- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 Blossom#1 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): - Fee-Private(Ninilchik Unit Tract 3)/ADL 389737 Ninilchik Field-Beluga/Tyonek 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): 6,795 3,416 6,795 3,416 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 110' 110' Surface 2,495' 10-3/4" 2,495' 1,586' 5,210 psi 2,480 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development El Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/15/2015 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS D - 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 Taylor Nasse Email tnasset hilcorp.com Printed Name Stan Porhola Title Operations Engineer / Signature _ � l'1 Z7 Phone 907-777-8412 Date j)/s COMMISSION USE ONLY ((( Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315-364-{ Plug Integrity ❑ BOP Test ►d Mechanical Integrity Test ❑ Location Clearance ❑ Other: ic-- L1666 p5,1, Gide s f ( 114,4 P= 2 7 7 /0)- ) . Spacing Exception Required? Yes CINo Q Subsequent Form Required: /0_4/10,7 (lam'J APPROVED BY Approved by:" COMMISSIONER THE COMMISSION Date: ///2//yC r Submit Form and Form 10-403 Revised 5/211!4' ' ifor 12 months the date of approval. Attachments in Duplicate / ORfG1tt4nAVII1 RBDMS JUN 2 4 2011ye -, 4 r.i • Well o Well:PrBlossom #1 Hilcorp Alaska,LI) Date:6/05/2015 Well Name: Blossom #1 API Number: 50-133-20648-00 Current Status: New Grassroots Well Leg: N/A Estimated Start Date: Est TD of well is 6/15/15 Rig: Saxon#169 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 215-015 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: 1413217C Current Bottom Hole Pressure: — 3,561 psi @ 8,283' TVD (MASP calculated in PTD) Maximum Expected BHP: — 3,561 psi @ 8,283' TVD (MASP calculated in PTD) Max. Allowable Surface Pressure: —2,733 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Blossom #1 is a grass roots development well targeting gas sands in the Beluga and Tyonek formations. This new well is estimated to reach TD on 6/15/15. The purpose of this work/sundry is to run the 4.5" completion tubing, jet the well dry with coil, and leave the well shut-in ready to perforate (proposed perfs to be submitted on a separate sundry). ,z Notes Regarding Wellbore Condition • Below procedure to be completed post 4.5"liner cleanout noted in PTD step#21.5. • Well will be filled with filtered 6% KCI. Drilling Rig Completion Procedure: 1. MU PBR polish mills. 2. RIH w/4-1/2" DP and tag up on liner top.Work polish mills inside tie-back receptacle. 3. Circulate btms up. POOH. Lay down 4-1/2" DP and polish mills. 4. MU completion w/seal assembly and Chemical Mandrel. a. Use conventional bands to secure%" control line to tubing(2 bands per joint). b. No SCSSV required (not within 660' of water or the highway). 5. RIH w/4-1/2" tubing to liner top. Land seals in tie-back receptacle. 6. Land 4-1/2" tubing hanger. 7. Test casing (4-1/2" x 7-5/8")to 2,000 psi for 30 min and chartfr /14 11" tit 8. Test tubing (4-1/2"tubing and 4-172" liner) to 5,000 psi for 30 min and chart. 9. Lay down landing joint. Set BPV. ND BOPE. NU 4-1/2" 5000#tree. Pull BPV. 10. Set TWC. Test tubing hanger to 250/5,000 psi.Test tree to 250/5,000 psi. Pull TWC. 11. RD Saxon#169 Drilling Rig. 12. Install IA x OA pressure gauges (7-5/8" x 10-3/4"). 13. Turn well over to production. Coiled Tubing Procedure: 14. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 15. RIH w/ 1.75" coil w/3.80" gauge ring to 11,800' MD and tag PBTD. POOH. • • Well Prognosis Well: Blossom#1 IIi!eorp AIa,.ka.LI) oalv'..-11- -- Date:6/05/2015 16. RIH w/CBL tool and run bond log from PBTD to+/- 6,600'. POOH. 17. RIH w/2-1/4"jet nozzle BHA to 11,800' MD and tag PBTD. 18. Displace well fluids with Nitrogen. a. Estimated volume of displaced 6% KCI is 180 bbl. 19. Leave well with +/-2,000 psi Nitrogen SITP. 20. POOH w/coil. LD 2-1/4"jet nozzle BHA. 21. RD Coiled Tubing. 22. Turn well over to production. Attachments: 1. Proposed Schematic 2. Rig ROPE Schematic 3. Coil BOPE Schematic 4. Wellhead Diagram H . • Ninilchik Unit Well: Blossom#1 PROPOSED SCHEMATIC D API:: 50-133-20648-00 Hilcorp Alaska,LLC CASING DETAIL 16" � 2 ! [1, Size Type Wt Grade Conn. ID Top Btm 16" Conductor 84 X-56 Weld 15.010" Surf 110' 10-3/4" Surf.Csg 45.5 L-80 BTC 9.950" Surf 2,495' 3 TOC @ 7 5/8" Prod.Csg 29.7 L 80 BTC 6.875" Surf 6,795' 10-3/4" 2,000' 4-1/2" Prod Liner 12.6 L-80 DWC/C-HT 3.958" 6,600' 11,915' TUBING DETAIL x 4-1/2" Tubing 12.6 L-80 BTC-mod 3.958" Surf 6,600' JEWELRY DETAIL No. Depth ID OD Item 4 5 t. 1 18' 4.000" 6.750" Tubing Hanger,4-1/2" " 6 t . .gip 2 19' 3.958" 4.500" Pup Joint 7-5/8" ' ,� 3 ±2,000' 3.813" 6.500" 4-1/2" Chemical Injection Mandrel Shoe @ 6,795' 4 ±6,600' 3.958" 4.500" 4-1/2"Seal Assembly A Mkr Jt 7,000' 4 1 ry5 ±6,600' 4.500" 6.500" Liner Tie-Back Receptacle : , 6 ±6,600' 5.000" 6.672" Liner Top Packer A Mkr Jt 7,500 I 12-kt }T A Mkr Jt 8,000 ,• Y� � PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) Date Size Status N. A Mkr Jt 8,500' Z./ ,'1 A Mkr Jt 9,000' , , ' , ? y ger ''' 6-3/4"hole 4-1/2" Shoe @ 11,915' PBTD=11,800'MD/8,174'TVD TD=11,915'MD/8,283'TVD Max Deviation:75 deg Max Dogleg:4 deg/100 Downhole Proposed Updated by STP 6/05/15 • • II Blossom#1 Completion Procedure Rev 0 Ilileorp Alanha,IIA: BOPE Schematic 111 X111 lii lit lii lit [II III 3.=" [5 Mode bb11 .. )1"S4bR �� tea. H 2-7/8"x 5" VBR 1.:,a. .,.. , 0) t a 41eigy s Mode t 7002 - I- II" 50,0 ;asi N 11"Blind . . r .„___,sll1 T.. IRI :';'.: ill II I 86 2 1/16 5M Kill Side d 1/8 5M Choke Side , 1 11irr T Model 7*> --- 4-1/2"Pipe Ram 0_cr, • .,_ . Iv u I.I ler Ilii Grade II lil ISI fl Iii .i ,--,,■ .ftii CJr. I-- � i iss l- - ,„, Revision 0 June,2015 • • • 11 Blossom#1 Completion Procedure Rev 0 Ililrnrp.%a.ka,1.1.1.: Choke Manifold Schematic fic /GI /f/6 /47 ' ? r - .< .,- 67 24 43.62 ( 43.62 61M I ';1.10. ,� e+ 16.43 14.62 •463 - �d43---- a/9 -0.19 ^ %�__J.19 0.19_ 10 0.19 ., lir • • n 1.1 �-,I~A 3n O t9 C� Ia.4gi'\ I A(� £ Alit Ill nbo `2 Ii- •.. •- i 9.009... ;'---- m I 0.19j 1 s- •&19J 0 0 ����.��...,1•i. 1 �, �6a• 7,64 ,I '11, r 5. V+ a l:T' I 9.84 AAI •111114 1.1 M. I 1 w o_w 0 161 019i �' err' sea. 4 ,46z ��� 4.4 I 1 14..2 36.W ���i� T .Ji .. 1,62 ,�1 A r0.19 _; 417. ,� t.'r �q� i � .. �,i . ail v an IM z. a 16� �� 'I 1 1050 it L I '1L o �;II `III iI 1Q ..!L. ulu,-0.19 Rw CID m 112 CHOKE 0.19 0.99 0.19 MANUAL 19M.910.79 0.19 OF/114 Ps�r -631 1452 14.62 14.62 14.62 631 !J 4352 4162 P�t3 Welt. - - 67.24 WEL. CAD 74-1'51-.447_ ' .� 1.LAYOUT 6M a 1CASK= L a xc" �Ir � .n-^r-wr Jam, min= s 4.-».�. _+..'9[ n N ,.Y 74 woo.1 • 9T094.u.l. . Revision 0 June,2015 • . Ninilchik Unit COIL BOPE Blossom #1 06/05/2015 11,1.-.,q,11,1.-.,q, tl., k.,.lilt Blossom#1 16 X 10 Y.X 7 5/8 X 4'A Coil Tubing BOP ILubricator to injection head N twt�i n 1.75"Tandem Stripper iii 1.I11I1 Blind/Shear =' 1/1610 ==Blind/Shear .I,'•t —II MIMS1 1111 Blind/Shear i= =-Blind/Shear"PO :1127 Di • —� 10E111 Slip =— Slip ■I,'•IJ .1111111111 1001E1 Pipe ,: iminPipe ,I,'• Mud Cross = � 4 1/16 10M X 4 1/,:= � 4 1/16 10M X 4 1/16 10M Outlet ii=_ w/2-2 1/16 10M full opening FMC valves I 'Hi ° 4-U- 1 =I -..-...E.' 8 It. mom Manual Manual MI= Manual Manual 2 1/16 10M 2 1/16 10M lel I.8 2 1/16 10M 2 1/16 10M Crossover spool to iai *' O.c 4 1/16 10M X 4 1/16 5M \� OLO 00' Jif dtaJS\c Valve,Swab,WKM-M, ��, ��� Ja„le��N� �e0 1,S 4 1/16 5M FE, HWO,DD trim f o 2,S Ja, �'�taco° �•< c - 31� g oce ..�� 31� ' _ /4 t a. i ,(--,: - �- Valve, Upper Master ”" ' """ WKM-M,4 1/16 5M FE, �(,o c' HWO,DD trim " .•!lila.. ,•, ;a Valve, Lower Master,WKM-M, ,•' 4 1/16 5M FE, HWO,DD trim Int'o MEINGrade Level • •• . iiNinilchik Unit Blossom #1 06/05/2015 II.i.-..,p 11,.1,,.1 1( Ninilchik Unit Tubing hanger,SME-CL,11 X 4%2 Blossom#1 EUE lift and susp,w/4"Type H 16 X 10'''A X 7 5/8 X 4 1/2 BPV profile,2-3/8 CCL,Alloy material BHTA,Otis,4 1/16 5M FE X 6.5"Otis Quick Union INI n •.14\«00, � �O p ,L a<a� Valve,Swab,WKM-M, ! ! �a\�e' FE, 0• 11`- 4 1/16 5M FE, HWO,DD trim PGo ,\AS \la\Jei F- ca'co� 3 311�,S Cr alO n •dor ,,, ,16.. _ — Valve,Upper Master ""="` WKM-M,4 1/16 5M FE, o c HWO, DD trim -- u.,. 11/ .w.. wuN. Valve,Lower Master,WKM-M, r 4 1/16 5M FE,HWO, DD trim 0r,` L� '4' i ` Grade Level — It Multibowl Wellhead,SMB-22, 11110111�I _ , T.4. 4 11 5M X 16%3M,w/ tI� ����_{ON' 1.I. 4-2 1 16 5M SSO '' Ii'" ' r e , e Elam A 4illia.i. i Starting head,Seaboard, :We; �j� UMW 16%3M X 16"SOW,w/ 2-2 1/16 5M EFO 1141 1N & hI14 4 T� 0%„ '7 5/8" 4 W' 1aM.. V rm z I5o15C Regg, James B (DOA) From: Shane Hauck <shauck@hilcorp.com> Sent: Monday, June 29, 2015 10:08 AM e7� C47-q'ls To: Regg,James B (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay Cc: Paul Mazzolini; Monty Myers; Luke Keller; Shane Barber- (C); rig169@saxonservices.com Subject: Saxton 169 06-26-15 Attachments: Total Gas Calibration 6-26-15.pdf; BOP Saxon 169 6-26-15.xlsx; BOP Test Sheet 6-26-15.xlsx; Chart for BOP test 6-26-15.pdf Mr. Regg Here is our Test sheet and back up paper work as requested Thanks 4aIA = Thanks, Shane R. Hauck Sr. Drilling Foreman Hilcorp Energy Company shauck@hilcorp.com Anch office: 907-777-8366 Cell: 907-250-2713 Rig: 907-776-6776 1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION /C- BOPE Test Report (All 6 Submit to: jim.reggaalaska.qov AOGCC.Inspectors@alaska.gov phoebe.brooksalaska.qov Contractor: Saxon Rig No.: 169 - DATE: 6/26/15 Rig Rep.: Duggans/Davis Rig Phone: 907-776-6728 Operator: Hilcorp Alaska, LLC Op. Phone: 907-776-6776 Rep.: Hauck/Barber E-Mail shauck@hilcorp.com Well Name: Blossom#1 PTD# 2150150 -- Sundry# Operation: Drilling: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly: X Test Pressure (psi): Rams: 250/4000 - Annular: 250/4000 - Valves: 250/4000 ' MASP: 2733 - MISC.INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P - Upper Kelly 1 P • Housekeeping P • Rig P - Lower Kelly 1 • P - PTD On Location P - Hazard Sec. P Ball Type 1 P - Standing Order Posted P - Misc. NA Inside BOP 1 • FP FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P - P • Annular Preventer 1 11" P • Pit Level Indicators P - P - #1 Rams 1 2 7/8"x 5" P - Flow Indicator P - P #2 Rams 1 Blind P Meth Gas Detector P • P - #3 Rams 1 2 7/8"x 5" P H2S Gas Detector P P - #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/8" P - Inside Reel valves 0 NA HCR Valves 2 3 1/8" P - Kill Line Valves 2 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc _Y L .-K%!n4- Time/Pressure Test Result System Pressure(psi) 3000 - P • CHOKE MANIFOLD: Pressure After Closure(psi) 1500 P Quantity Test Result 200 psi Attained(sec) 21 P No.Valves 13 FP ✓ Full Pressure Attained (sec) 98 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (#and psi): 4 @ 2650 P ' CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 2 '/ Test Time: 8.5 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Test delayed(AOGCC approved)due to stuck drill string.All components pressure tested 250psi 5 minutes and 4000psi 10 minutes on 4-1/2"test jt.Total Safety calibrated/tested all gas alarms. F/P test#2 bleed air out IBOP re test(good); F/P test#9 functioned CMV#5
 retested (good). Test#11 was retest Annular t/4000psi but did not like chat Test#12 was retest of annular t/4r10n nsi clue to nnlv tested t/25n0 nsi nn Test#1 AOGCC Inspection 24 hr Notice Yes Date/Time 6-23-2015 09:50 Waived By Jim Regg Test Start Date/Time: 6/26/2015 0:30 (date) (time) Witness Test Finish Date/Time: 6/26/2015 9:00 444-A-CLU � �,` )Q S 4- CGS' ( l ) PE,- rej- S - (z pis) '-7 ' SaFe'tf Ckc b+er crti s'f sr -L TE—ST- ( j 0) Form 10-424(Revised 06/2014) 2015-0626_BOP_Saxon169_Blossom-1.xlsx Sa m, (c,61 &f5- 'cis; 111 15 30 0 3/655,„ 1 -01 (� ZISOI s0) 45 45 T( "5° ' ` -5500 SSpo 45 <3 — --`8000 ao < p,,o__---,----. � \ �-- f 4500 A\ f \ q�� 14„3013 .� • , } / 'h . /,-,-___L_-_,.- ,� - ' s - � \i p- o - 0 � i p0 ” `�`� NN" c5s,, (5%/ �0 ` . �, 300 i' ?°° 25 0 p G fZ>z"'‘, , 11 ° O % b +ppt °�. fes_' O00 X00 \� 150 / \ \-5 0 a / r \ y ws00 �. J gyp , „ ,, 'v__- ,' �O , i �cP � J Cs \N u, n pi Cy, p CT 00�� i� /S' J NO O p 0~ d P f (;) t� a (,_5,\,, O p ,1-- — {/ O r cp ( 1 Z �- \-,, ,,,-i _-`i y - o.. o E I w h I C O O Sy ( con O p. A r Sl ./. G n N. - , \ Z ti O cn to ,'f \ \ \ 4 \f ../\_C3 i // O \ \ O S '� � /1 /1 . t o \ O J , C 1 ��' /� 7 i \\ V 00 J7=�._ 1 -i raft., 000 ! OGi /' 1 \ Oa S / �'' Q0 0 O j ' \\ © Off\ f 00 ,/ 00 Os-) .�, , f\\\7 O ,' �,, ! 1005 f / f1 ;E± _ _ '°°SZ , -- i f 00) �� J O \. , , 0000 ,96 ,\ / �..l�; J100 _ f - 0pp� . ,< / o,00e, \// o� / r,.0 00c \ • -,. OpS �✓ c' '. 00 �i off' �`.,° ooS //r' I - .pop 1 i' °QS _ oo`�. sr __ oS ,----- SP 6 /� of st HILCORP -uhy 1014 BOP TEST SHEET DATE: 26-Jun-15 RIG CONTRACTOR: Saxon RIG # 169 TIME: 2:30:00 AM WELL NAME: Ninilchik field Blossom #1 TYPE OF OPERATION - (DRILLING /WORKOVER / OTHER): Drilling HILCORP REP: Shane Hauck/Shane Barber RIG SUPERVISOR: Kevin Duggans SUPERINTENDENT: TESTING COMPANY: Saxon DP SIZES: 4-1/2" BOP SIZE & RATING: 11" 5k Test# Components Tested Minutes Held Low PSI High PSI Pass/ (Low/High) Fail 1 Annular, Manual Choke, Manual Kill, TIW 5min/10min 250 2500 P 2 Top pipe ram (vbr) Mez. Kill, CMV, 1,2,3, Dart, 5min/10min 250 4000 F/P , " lower IBOP 3 Top Pipe ram (VBR) KILL HCR, Choke HCR, 5min/10min 250 4000 P TIW 4 Top pipe Ram (VBR) Manual kill, Manual 5min/10min 250 4000 P Choke, TIW, kelly cock 5 Btm pipe Ram (VBR), TIW 5min/10min 250 4000 P 6 Blind Rams, CMV 4,7,8 5min/10min 250 40000 P 7 Blind rams, CMV 6, 5, 13 5min/10min 250 4000 P 8 Blind rams CMV 9,12 5min/10min 250 4000 P 9 Blind rams CMV 5, 10 5min/10min 250 4000 F/P v 10 tested aginst Manual choke and remote choke 5min 0 1500 P 11 Retested annular ( not happy w/ chart) V 12 Retested Annular, Manual Choke, Manual Kill 250 4000 P as per PTD Accumulator Test Accumulator Manifold Annular Preventer Type Closing Time Initial Pressure 3000 1500 850 T3- Energy 14 Final Pressure 1500 1500 840 Re-charge Time 21/200, 98/full psi Hilcorp Representative Signature: Rig Supervisor Signature: Contract Testing Representative Signature: EXPLANTATION OF TESTS ON NEXT PAGE. ATTACH BOP AND MANIFOLD SCHEMATIC. • HILCORP • ito „ ,:,), 40,0,, ,,,, , „.._ k,,,„.„,. .......„ BOP TEST NOTES HP Fest # 2 bleed air from IBOP re test good F/P Test # 9 fuction test CMV 5,10 and retest good Test #11 was re-test of annular to proper high test as per PTD ( but did not like chart) -" Test #12 was re-test of annular to proper high test as per PTD * 9 C)6f7r• 1( `I , , • • • ) 1- 0 PE TE-e,r(‘,-26-i 5) Total Safety U.S.,Inc. 209 E.51st Avenue ,,,,`?"•>, Lno Anchorage,AK 99503 Wea; TOTAL SAFETY of Phone:(907)743-9871 Fax:(907)743-9872 " • , AS DETECTION SYSTEM TEST SHEET Customer: - ' , , ; Onshore: Offshore: f Report Date: , Time: -, . AFE/Jobit: Rig/Location: / , - , : Drilling Company: Company Representitive: . ', Telephone Number: _ Total Safety Technician: Current Site Activity: Type of System: ' - Type of Test; Calibration Bump Test .Sensor#1 ,/,... ,- ,, „ "", : ":, : - Sensor#2 „ - - ., ' Sensort.I. Type of Sensor: 'i i "` Type of Sensor: //,'.,, Type of Sensor: ....d,HA' Location: , , , Location: Location: - , Calibrated from: ° , Calibrated from: =, , Calibrated from: Bumped at: • Bumped at: ,, Bumped at: Low alarm<30 seconds: ,— Low alarm<30 seconds: =-.--"" Low alarm<30 seconds: Battery Voltage: ,,, Battery Voltage: , Battery Voltage: Comments: ' = Comments: =„ , r I , Comments: /1: :e , ,.., Sensor#4 ' , Sensor#5 - ,, Sensor#,6 S Type of Sensor: , - • Type of Sensor: ,,, - '' Type of Sensor: ,' Location: , Location: Location: Calibrated from: - Calibrated from: ,/,-- Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm<30 seconds: Low alarm<30 seconds: ,,,,-., • Low alarm<30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: ,, c Comments: , / „'„ ,/"-- Comments: Sensor#7 ' ; . Sensor#8 Sensor#9 - - Type of Sensor: : i i Type of Sensor: ... .- ." ,, Type of Sensor: Location: Location: „ LocatiOn: Calibrated from: , ' Calibrated from: , Calibrated from: , Bumped at: , Bumped at: 4; f" Bumped at: Low alarm<30 seconds: - Low alarm<30 seconds: „,, Low alarm<30 seconds: ' -- Battery Voltage: Battery Voltage: , ' -,- Battery Voltage: Comments: =- Comments: ,/ ,-, 4, „-`,- - ././„/ Comments: Sensor#10 : ,. ' Sensor#11 ' Sensor#12 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: -„, Calibrated from: Calibrated,from: Calibrated from: , a Bumped at: ,,,,,„, Bumped at: ----„,..„,„ Bumped at: ---,-,„ Low alarm<30 seconds: ''"-- - Low alarm<30 seconds: - Low alarm<30 seconds:, Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: 7S 5S S. , . Total Safety Technician Company Represenitive ,- -- kt Date: Date: White-Office Canary-Customer Pink-File ti OF 77.14, 0 \ I//j,> s THE STATE Alaska Oil and Gas w�,;- -__;=a-‘�, of AT AsKA Conservation Commission iWitt333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool,Blossom#1 Hilcorp Alaska, LLC Permit No: 215-015 Surface Location: 1155' FSL, 373.7' FEL, SEC. 14, T1N, R13W, SM, AK Bottomhole Location: 1389' FSL, 1982' FWL, SEC. 11,T1N,R13W, SM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. Well is considered to be a development well by AOGCC,not exploratory. Target zone is a known pool. 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 Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: Since this is the first well from a new drilling pad: mud log, gamma ray, resistivity, caliper, and porosity logs from the base of conductor pipe to the total depth of the well. 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. 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, Cathy . Foerster Chair DATED this ji day of March, 2015. RECEIVE.. STATE OF ALASKA AL-,oKA OIL AND GAS CONSERVATION COMMON JAN 14 2015 PERMIT TO DRILL 20 AAC 25,005 A n nr• la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑✓ ' 1 c.Specify if well is proposed for: Drill - ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas[ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory �I :iervice- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas El2.Operator Name: i.{,� V6/4 5. Bond: Blanket o Single Well ❑ 11.Well Name and Number: Hilcorp Alaska, LLC Bond No. 102235244 Blossom#1 3.Address: 6.Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 MD: 11915' TVD: 8283' Ninilchik Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga/Tyonek Gas Pool Surface: 1155 FSL,373.7'FEL,Sec 14,T1 N,R13W,AK (-e-i-Tr(vejt,'.CL;l.inilchik Unit Tract 34DL 389737 S-,1:- / 'jil Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1438'FNL, 1922'FEL,Sec 14,T1N,R13W,SM,AK N/A March 1st,2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1389'FSL, 1982'FWL,Sec 11,T1N, R13W,SM,AK 3095.55 1837'to Unit Boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 233 feet 15.Distance to Nearest Well Open Surface: x-231717 y-2258334 , Zone-4 GL Elevation above I 215 feet to Same Pool: >7,000' 16.Deviated wells: Kickoff depth: 250 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 75 degrees Downhole: 3561 ' Surface: 2733 - 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) 13-1/2" 10-3/4" 45.5 L-80 BTC 2500' 0 0 2500' - 1574' 1424 ft3 9-7/8" 7-5/8" 29.7 L-80 BTC 7500' 0 0 7500' 4137' 1490 ft3 6-3/4" 4-1/2" 12.6 L-80 DWC/CHT 4615' 7300' 3950' 11915' 8283' 1000 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 ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch n Drilling Program RI Time v.Depth Plot ❑ Shallow Hazard Analysis Hi Diverter Sketch [1] Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Email Printed Name Luke Keller / Title Drilling Engineer Signature Phone (907)777-8395 Date 1/14/2015 Commission Use Only Permit to Drill API Number „ l��r Permit Approval See cover letter for other Number: i iS-1 50- (.53'"z0i,4jv �6,e.;Date:, fi 6 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 shales: EL Other: y, (tC C= ,r 1i 6/.) l i( Samples req'd: Yes ❑ No El Mud log req'd:Yes❑ No[1]1 H2S measures: Yes ❑ No[ Directional svy req'd:Yes❑ No❑ /L.foi 5or �3-/- • Spacing exception req'd: Yes ❑ No gInclination-only svy req'd:Yes❑ No❑ 6)ir- ..t.,4_ ...,7 ,,...7 (-1-4:_ate-.9 1,1C7V"" Cc5 Pry 4- 4 cli,N. Cqp42-r.-4-i 45 MA APPROVED BY Approved by /41 COMMISSIONER THE COMMISSION Date -453� � Z+' Submit Form and Form 10-40 (Revised 10/2012) JE3a1d J2�t f the from the date of approvala20 C 25.005(g)) Attachments in Duplicate fiit" vv ivHHt�� ?/j7i�/ 37>z:,.cfc Hilcorp Luke Keller Hilcorp Alaska, LLC Energy.Company Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 1/14/2015 Email Ikeller@hilcorp.com Commissioner Alaska Oil & Gas Conservation Commission RECEIVED A E��� 333 W. 7th Avenue R C Anchorage, Alaska 99501 JAN 14 2015 Re: Blossom #1 AOGCC Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Blossom #1 Exploration gas well. Blossom#1 is a grass roots exploration gas well to be drilled off the Blossom Pad. The well is a . 11,915' MD/8,283' TVD deeper pool test of the Beluga/Tyonek gas pool in the Ninilchik Field. The Tyonek is the primary target, but if unsuccessful, there are secondary targets in the Beluga. The base plan is an "S-Turn"wellbore reaching a maximum inclination of 75 deg and a 6,992'vertical separation. Drilling operations are expected to commence approximately March 1st, 2015. The Saxon Rig# 169 will be used to drill and complete the wellbore. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, / Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 i Hilcorp LLC Blossom #1 Drilling Program Ninilchik Field Revision 0 January 13th, 2015 • Blossom #1 Drilling Procedure If dem v Alaaka.IAA 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 10 10.0 N/U 21-1/4"2M Diverter 11 11.0 Drill 13-1/2"Hole Section 14 12.0 Run 10-3/4"Surface Casing 18 13.0 Cement 10-3/4"Surface Casing 20 14.0 BOP N/U and Test 23 15.0 Drill 9-7/8"Hole Section 24 16.0 Run 7-5/8"Production Casing 27 17.0 Cement 7-5/8"Cement Procedure 30 18.0 Drill 6-3/4"Hole Section 32 19.0 Run 4-1/2"Production Liner 37 20.0 Cement 4-1/2"Production Liner 40 21.0 Wellbore Clean Up&Displacement 43 22.0 Production Tubing Installation and Perf 44 23.0 BOP Schematic 45 24.0 Wellhead Schematic 46 25.0 Days Vs Depth 47 26.0 Formation Tops 48 27.0 Anticipated Drilling Hazards 48 28.0 Saxon Rig 169 Layout 51 29.0 FIT Procedure 52 30.0 Choke Manifold Schematic 53 31.0 Casing Design Information 54 32.0 9-7/8"Hole Section MASP 55 33.0 6-3/4"Hole Section MASP 56 34.0 Spider Plot(NAD 27)(Governmental Sections) 57 35.0 Surface Plat(As Built)(NAD 27) 58 36.0 Offset MW vs TVD Chart 59 37.0 Drill Pipe Information 60 • • Blossom #1 Drilling & Completion Procedure Harm p rt at.ka,IIA. 1.0 Well Summary Well Blossom#1 Pad&Old Well Designation Blossom#1 is a grass roots well on the Blossom Pad Planned Completion Type Gas lift on 4-1/2"production tubing Target Reservoir(s) Beluga&Tyonek formations Planned Well TD, MD/TVD 11,915' MD/8,283' TVD PBTD,MD/TVD 11,800' MD/8,174' TVD Surface Location(Governmental) 1155 FSL, 373.7' FEL, Sec 14, TIN, R13W,AK Surface Location(NAD 27) X=231717,Y=2258334 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1438'FNL, 1922'FEL, Sec 14, T1N, R13W, SM, AK TPH Location(NAD 27) X=230214.24, Y=2261048.87 TPH Location(NAD 83) BHL(Governmental) 1389' FSL, 1982'FWL, Sec 11,TIN, R13W, SM, AK BHL(NAD 27) X=228900.72,Y=2263906.53 BHL(NAD 83) AFE Number 1413217D AFE Drilling Days 38 Days AFE Completion Days AFE Drilling Amount $6,707,600 AFE Completion Amount $1,034,000 Maximum Anticipated Pressure (Surface) 2733 psig Maximum Anticipated Pressure (Downhole/Reservoir) 3561 psig Work String 4-1/2" 16.6# S-135 CDS-40 (Saxon Owned String) KB Elevation above MSL: 233' GL Elevation above MSL: 215' (NGVD29) BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure flikurp Alaska,LII: 2.0 Management of Change Information Hileorp Alaska, LLC Hficorp Lomity Company Changes to Approved Permit to Drill Date: 1-8-2015 Subject: Changes to Approved Permit to Drill for Blossom #1 File#: Blossom #1 Drilling Program Any modifications to Blossom#1 Drilling Program will be documented and approved below Changes to an approved APD will be c.ommtlarrate4-to the,BLM and AOGCC. 44. 46 f. zi, See Page Date Procedure Change Approved Approved By By • Approval: Drilling Manager Date Prepared Drilling Engineer Date Page 3 Revision 0 January, 2015 • S Blossom #1 Drilling & Completion Procedure Harm p Ala ka,LI C: 3.0 Tubular Program: { �"`'"^ Ji ji cA r' " sR-g 1'; �. 7€s #�; ':rte �' Ji h; .)11 -.T,1".:', 5 ii, �i '- ° la � '®.. „..,,,,,701:4,11,1,;„74v7 � _▪ a ��� �'�� J� i `' ill � , �+ -:14..18i 1i ! ? � t x3▪ r i, " ar- a-»''as, � Cond 16” 15" - - 109 X-56 Weld 13-1/2" 10-3/4" 9.95" 9.875" 11.75" 45.5 L-80 BTC 5210 2470 1040 9-7/8" 7-5/8" 6.875" 6.75" 8.5" 29.7 L-80 BTC 6890 4790 683 T 6-3/4" 4-1/2" 3.918" 3.833" 5.0" 12.6 L-80 DWC/C 8430 7500 288 4.0 Drill Pipe Information: r. i � > l l TJ ID TJ OD Wt Grade - Conn Burst Collapse,...,..--,4,,''i n ,1 . ` A i_ . �( ). (in) (#/ft) (psi) (psi) (k4-lbs}�J,' Al! 4.5" 3.826 2.6875" 5.25' 16.6 S-135 CDS40 17,693 16,769 468L All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 January, 2015 • i Blossom#1 Drilling & Completion Procedure tide. Ala.la,II C 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; mmeyers@hilcorp.com, lkeller@hilcorp.com, &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. Matt Hogge: 0: 777-8418 C: 907-227-9829 2. Spills: Julieanna Orczewska: 0:907-777-8444 • Notify Drlg Manager&Drlg Engineer: 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 2. Luke Keller: 0: 907-777-8395 C: 832-247-3785 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As-Run" Casing tally to lkeller@hilcorp.com & cdinger@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller(ahilcorp.com & cdinger@hilcorp.com Page 5 Revision 0 January, 2015 • Ill Blossom #1 Drilling & Completion Procedure Ilikorp Alaslsa,LTC 6.0 Planned Wellbore Schematic CASING DETAIL . . , it 1 ' !, ...., Size Type w....t Grade Conn, ID Top Btrn 16" 2 16" Conductor 84 X-56 Weld 15.010" Surf 78' .,..... 3 P- 'fil r: i l. 10-3/4" Surf.Csg 45,5 1-80 BTC 9.950" Surf 2,500'• Ar ' TOC(IT' .• e, 7-5/8" Prod.Csg 29.7 L-80 BTC 6.875" Surf 7500'. 10-3/4 ''r• ,., L._IA, 2,300' ,,,c.:1 4,*1 r 4-1/2" Prod Liner 12.6 1-80 DWC/C- HT 3.958" 7,300' 11,915'. TUBING DETAIL BTC- 4-1/2" Tubing 12.6 1-80 d 3,958" Surf 7,300' mo1....N. M a ! g Depth ID JEWELRY DETAIL OD Item 1 18' 4.00" - Tubing Hanger,4-1/2" 2 19' - PupJoint 3 —170' 44/2'SSSV 4 '.- I 5 —7,200'4 _ —7,140' 4-1/2"Chemical Injection Mandrel 7-5/8"x 4-1/2"Retrievab le Production Packer 6 —7,250' 4-1/2"X-Nipple 7 —7,300' 4-1/2'Tailpipe ; • -..a- '..."4 ..Jewelry set depths will be finalized after reviewing the open hole logs** 1'1,1'4 6 X2 i# 7 , ' : Tie Back Receptacle Liner Hanger Packer @ 7,300' 7-5/8" ;411';,..' .-.. Shoe Ea 7,500' i '4-Tr';) .*,..AE i'"f Nx. ' 0,SPr 1--,.-4:-:; ili, ''''''-' 1'1 6-3/4"hole ry " '..... 4-1'1TM ' -'4 4:74'4k; Shoe ED 11,915' PBTD=11,800'MD/8,174'TVD TD=11,915'MD/8,283'TVD Max Deviation:75 deg Max Dogleg:4sig...en00 Page 6 Revision 0 January, 2015 410 Blossom#1 Drilling & Completion Procedure t1 Ieorp 7.0 Drilling / Completion Summary Blossom#1 is an exploratory Tyonek and Beluga well. Primary objectives are Upper Beluga through Beluga 60 reservoir sandstones;then while drilling determine the top of the Tyonek structural top in order to determine whether or not to drill the well to it's planned TD. Location follows the Falls Creek-GO fault down the plane into the four-way closure within the Falls Creek fault block. Four-way, three-way, and fault closures are all anticipated at various levels. Play is based on 3D data. The base plan is an"S- Turn"wellbore reaching a maximum inclination of 75 deg and a 6,992' vertical separation. Drilling operations are expected to commence approximately March 1st, 2015. The Saxon Rig # 169 will be used to drill and complete the wellbore. After the rig has departed, the well will be perforated rig less. All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand, 1800 ppm at the 505 — 535' sand, and 6000 ppm at the 1040' sand. Furthermore, the TGAS (total gas) curve from offset mud logs begins registering shallow gas at depths just below the sandstone bed at 200'. • Surface casing will be run to 2500' MD and cemented to surface to ensure protection of these resources. 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 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 ,p O ' 2. N/U 21-1/4"x 2M diverter. 3. Drill 13-1/2" hole to 2500' MD. Run and cmt 10-3/4" surface casing. 4. N/D diverter,N/U &test 11" x 5M T3-Energy BOP. 5. Drill 9-7/8"hole section to 6,500' MD. Run and cmt 7-5/8" intermediate casing. 6. Drill 6-3/4"production hole section to well TD. Run and cmt 4-1/2" production liner. 7. TIH w/clean out assy, clean out liner to landing collar. Displace mud to filtered completion fluid. 8. TOH, LDDP, RIH w/production tubing. 9. N/D BOP, N/U temp abandonment cap, RDMO. Page 7 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure nileorp Alaska..l,i,t: Reservoir Evaluation Plan: 1. Surface section: Mud logging only (c.-wcw K �`�l`" `4 a`` ►�'�`b .� 2. Intermediate section: GR+ Res +Den/Neu LWD +mud logging 3. Production section: GR+ Res +Den/Neu LWD + mud logging 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 and completion of Blossom #1. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 psi for 5/5 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 AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: At, % �f ,a (^(mss>: - _ r q LIA54 • Hilcorp respectfully requests a waiver to the 7-day BOP test requirement for exploration wells. Although Blossom#1 is deemed an exploration well according to the well classification matrix, there have been numerous offset wellbores drilled and the pressure regime is well documented and understood. Rig 169 also has a well-documented history of BOP tests in Alaska. • Hilcorp respectfully requests a waiver to the "H2S Measures"requirement for exploration wells. Specifically with regards to the Cascade System and SCBA escape pack requirement. There have been several recent offset wells drilled in the 2 years (Falls Creek 6, Falls Creek 5, Frances#1, Page 8 Revision 0 January, 2015 • i Blossom #1 Drilling & Completion Procedure ndem p A1;1411,1J Susan Dionne#8). None have encountered H2S. Hilcorp will have a gas detection system R/U which will include H2S detection. H2S scavenger will also be on hand to add to the mud system. Full mud logging suite will be R/U from surface casing shoe to TD of the well. More information is available per this request if requested by the AOGCC. Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 13-1/2" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/4000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 9-7/8"&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 250/4000 • 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. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg(a�alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz cr alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Page 9 Revision 0 January, 2015 • Blossom#1 Drilling & Completion Procedure Fiilcorp Alaska,IAA 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) 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 100' below ground level. 9.2 Dig out and set cellar. Ensure to level area around cellar so drlg sub structure is level. 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 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.8 Mix spud mud for 13-1/2" hole section. 9.9 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 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 10 Revision 0 January, 2015 >/ • • Blossom#1 Drilling & Completion Procedure F{I�COrp (. 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4" Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA (Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. f, it Te--1--t' a- 10.3 e... ca- 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking. • A prohibition on ignition sources or running equipment. • A prohibition on staged equipment or materials. • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 11 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure Ht.leot v<ki2_.,>,H,11 10.5 Rig and Diverter Line Orientation on Blossom Pad: PROPERTY LINE - _ . D1}i \ ourCH .4. 40 400' kit IGHT �V "_ I Illvot 4 g II+ o I I PROPOSED PAD , AREA•120,000 S.F. I FG=215.D , �I � E1-���—PERIMFR DRANP!-iE DITCH - 2'DEEP,2:1 SLOPES SEC rnCII 1 I `---- FILL SLOPE.. II I 2o ii , ., ,,,, „, . 11 i.'f 3 €.f .. ,,,, ,izi " , ,,,,, ,, , • .. , . ,, . , . .....__ , , „, „.„ ,, , .. r _ , I , ,D _ �,„ii ii ,g1 ., �a. , I i agg 1 ,4 AREA - I ll i II I , , € PERIMETER C ul�IAJ3E DITCH '1 % ( ' �� � 2' DEEP, 2:1 SLOPES � Page 12 Revision 0 January, 2015 0 • II Blossom #1 Drilling & Completion Procedure flilet)]p kla.,ka,III 10.6 Diverter Schematic Diverter Schematic For 13-W Hole Section • IP - = - - - Ill 111 ill ill III lIl 1ll ill Annular Preventer - - - - _ 111 111111111111 Knife Gate 111111111111 Ill _ ii,fIzti. _ NW 16"Diverter line ,_- Diverter Tee,21-W x 21-14"x f--_-i : 2M WI 16'"ANSI 150 outlet _ , ,,,.. "'" 01 10/00...,44 , 11111I / 1 III I I I 16-%"3M x 21-1/4"2M DSA iii .! i . . ... i Seaboard 16-W 3M Casing head Assy - 1 16" Page 13 Revision 0 January, 2015 • i Blossom#1 Drilling & Completion Procedure nilrorle.4laxka, ,u: 11.0 Drill 13-1/2" Hole Section 11.1 P/U 13-1/2" 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. • Ensure motor setting can achieve 5 deg/100' DLS in surface hole. Minimum of 1.5 deg AKO is recommended. 11.2 13-1/2" BHA (No LWD in surface hole BHA): tokoth (ft) COMPONENT DATA on Igi 67 tocte ion time& um .iii � /��i� ..,. � �rl�m a�_.,��$.. �in) .'- ��lin) lin)�'� � ..; .. r�_ .- , HOBS 9HC1GRC Mi Itaotr, ® 8.004 3.378 13500 14076 p 6 5'E REG 1.010 1.014 Nog8"SperryO nl i Lobe 415-5.3 stg 8.000 5.000 12'1.08 6 7"H90 32.00 33.00 11111 Stabilizer 13250 ® 8'MWD DM HOC 8.000 1.920 161.44 B 5-5/8"REG 8.75EIBMINI En ill 8"Inline Stabilizer(1CS) IIIIIIIIIIIIII 8.000 1.625 = 3.84 8'MWD TM HOC 8.410 1.920 166.18 B 6 5i8'REG 9.50 55.05 El 8"Non Mag Flex DM Cotler 8.000 150,13 BEs-5t8'REG 29.50 ® 8"Nan Mag Flex DMI Cotler 8.000 �_ 150.13 B 6-5'8'REG 30.00 E 8'NM Battle Neck XD SubINIMIE 8.00EEammi 149.18 s 2.25 116.80 ® 6-314'Nan Mag Flex Drill Colter 6.750 2.810ill I. 100.82 B 4-1)2".F 30.00 14680 10 6-3(4"Non Mag Flex Dr'I Coker 8.750 2.810 iii100.82 3000 176.80 ® X-0 4 tit'IF P x 4 112"CDS 40 B 6.500 2.750 _ 92.85 B 4.5"COS 40 2.75 4 ils 4 tt2"CDS40 HWDP 4.500 Ellin.13112IIIIIIIIIIIIIII 122.00 341.55 ® X O 4 1,`2'CDS 40 P x 4 1e"2"IF B 6.500 2.750 82.85 2.75 1111111304 343D Ell 6.480 2.750 92.45II3EMI 32.00 336.30 ® X041(2'1FPx412"C05408 R 6.500 2.188 100.28 84.5"CDS 40 2.75 33905 15 0,4 1P2"CDS40 HWDP 4.500EMI MEI 36.80 460.00 799.05 4°#Tout 79905 BIT DATA Bit Number Nozzles : 3x16,1x14 Bit Size {in) 13.504 TFA (in2) :0:7394 Manufacturer - ROBS Dull{hada In Model : 0HC1C,RC Dull Grade Out Serial Number . Page 14 Revision 0 January, 2015 . • • Blossom #1 Drilling & Completion Procedure flilcorp Alaska,lit 11.3 Primary bit will be the Security 13-1/2" QHC1GRC Milled Tooth Bit. These are available from Halliburton. PRoDuCl'SPECIFICATIONS APPIr -., IADC C'nde I 17W Total Tooth C011in tiage}tow Tooth Count 3,6 Journal Angle 33* si ,Nlinp.:4110. off.,0,14.) 4 JO Nozzle Types: Standard 83244 Extended 31006 Center Jet i If Center Jetted)501813 Ti.Connection 641 (Ain Reg.} tZrt,-'nig Recorrancitsled hlake.Up Torque* 2/4001E32,1K10 Ft*Ilits. Bit Weight i Boxed) 260 Lbs.(II 8 Kg.) kni,Art,,,,, . " hit itiottukor I Mat.Nliegaeynt I lit17711144911 .-', ,', i ,11i, . jrgir;'le 'PRODUCT FEATURES ii NOW patented DgettittidT4 100411 bit design, • . ,':' 0 ; 4 No • Pigritiethry Hiturionst TECH2.000114(nil With kanifacieg on casting iaructure and gage, 2riAl'Zi,14,," -- * A ..• « Tungsten carbide'serf inserts in gage teeth for added gage protection, "" lit44-nr'''' • Premium bearing and seal configuratima suitable for both rotary and . nillii'' • :,4L,',----,,„:,,,,i 0 maim-wheat ions. .... ,. e Innovative mechanical pressure compensating system provides reliable pressure equalizathin and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill Ming tonme, • QuadPaekt Plus Series itieorporates its suceessful longevity" features and patented engineered hydraulics syStent rig optimal cleaning efficiency. • Cann.id.Ct frAttir0 to prevent bit hill ng problem Material#540030 *Calculatioon bawd on renotratantinitionn nom API nod NO-joint manufacturers tt"2014 Halliburton,All rights reSeIVed.Sales of Fialliburton products and services will,hc I .accord solely with the I S and conditions contained in the coon act between Haiti butt and the customer Mat is(11111wattle to the sa s. :"..,,,o,,n4'ar,:`,":,:astIff3.4J:"441.;:ntrgnyjit::"!•:.1ft0/0/4*,, ,,,,,,,64,,m4-'• Page 15 Revision 0 January, 2015 • • Blossom#1 Drilling & Completion Procedure II lee p 4h ka, 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 No LWD tools will be run on the 13-1/2"hole section. 11.6 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.7 Drill 13-1/2" hole section to 2500' MD / 1574' TVD. Plan is to set the surface casing shoe through the base of the build section along the tangent at 75 deg. • Pump viscous sweeps as often as necessary and maintain mud rheology to ensure effective hole cleaning. • Pump at 550 gpm. This gives us an annular velocity of 83 fpm, which is borderline for effective hole cleaning. 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. Work through coal seams once drilled. • 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 btwn 2450' & 2550' MD. • Take MWD surveys every stand drilled (60' intervals) Page 16 Revision 0 January, 2015 i Blossom#1 Drilling & Completion Procedure I�Y`Yli'p 4 H.I.I.(. 11.8 13-1/2" hole mud program summary: No weighting material will be required in the surface hole section. However, enough barite should be available 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: MD # Mud Viscosity PV YP API FL LGS Weight 78'-2,500' 8.8—9.5 . 250- 85 40-20 75 -25 <10 <15% System Formul'dtiom-AQUAGEL/freshwater Spud Mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 -20 ppb caustic soda 0.1 ppb(8.5 —9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8—9.5 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb 11.9 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.10 TOH with the drilling assy, handle BHA as appropriate. Page 17 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure 11ileor1 41a..1,a.IIA 12.0 Run 10-3/4" Surface Casing 12.1 R/U and pull 15.375" wearbushing. 12.2 R/U Weatherford 10-3/4" casing running equipment. • Ensure 10-3/4" 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 10-3/4" 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. Estimated torque to reach base of triangle: 10,750 ft-lbs. • 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. 10-3/4" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 10-3/4" 10,750 ft-lbs Page 18 Revision 0 January, 2015 ! ! Blossom #1 Drilling & Completion Procedure Rilrotp Ala.ka,LI( Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performsance data. Size , ea m Wall �„,, a Grade B..n.„.. a Connection e,w a Unit 1/1 Pipe Body Data GEONIETRy I Nominal OD 10.750 in Wall Thickness 0,400 in API Drift Diameter 9,794 in !Nominal Weight 45.50 lbstft Nominal ID 9.950 in Alternate Drift Diameter 9.875 in Plain End Weight 44.26Ibsl'ft Nominal Cross Section 13.006 shin , ' ,` };r� Il PERFORMANCE Steel Grade 180 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 1,040,000 lbs Internal Yield Pressure (5,210 psi Collapse Pressure 2,470 psi Mr i Connection Data GEOMETRY Regular OD 11.750 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORIAAIICE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi ;Joint Strength 1,063,000 lbs Internal Pressure 5,210 psi Resistance m - --°'^--- s ry eraa>'lst-lydn`1®re �l arirr=? ops I Print Contact Us Ver 8.6 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. Page 19 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure IIdem p.tIa,»ka.I 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. 13.0 Cement 10-3/4" 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. • 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. 13.2 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.3 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. Pump remaining 35 bbls 10 ppg spacer. 13.4 Drop bottom plug. Mix and pump cmt per below recipe. 13.5 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(BBLS) Vol(ft3) LEAD: 80' x .106 bpf= 8.5 47.8 16" Conductor x 10-3/4" casing annulus: LEAD: (2000' —80')x .065 bpf x 1.5 187.2 1051 13-1/2" OH x 10-3/4" _ Casing annulus: Total LEAD: 195.7 1100 ,45L-' 5'Y\ TAIL: (2500'-2000')x .065 bpf x 1.5 49 275 13-1/2" OH x 10-3/4" _ Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 10-3/4" Shoe track: Total TAIL: 58 324 7-51 53C Page 20 Revision 0 January, 2015 l `; ! • Blossom#1 Drilling & Completion Procedure Riicorp LL[: Cement Slurry Design: Lead Slurry (2000'MD to surface) Tail Slurry (2500'to 2000MD) System Blend Conventional Density 12 lb/gal 15.2 lb/gal Yield 2.44ft3/sk 1.26 ft3/sk Mix Fluid 14.437 gal/sk 5.76 gal/sk Base Fluid 14.417 gal/sk 5.76 gal/sk Expected 5 HR 3 HR Thickening Code Description Concentration Code Description Concentration D901 Cement 94 lb/sk D901 Cement 94 lb/sk D046 Antifoam 0.2%BWOC D046 Antifoam 0.2%BWOC D020 Extender 2.6% BWOC D065 Dispersant 0.4% BWOC Additives D079 Extender 2% BWOC D167 Fluid Loss 0.2% BWOC D110 Retarder 0.02 gal/sk cmt S002 Accelerator 0.25% BWOC 13.7 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. 13.8 After pumping cement, drop top plug and displace cement with 9.2 ppg 6% KC1/PHPA drilling fluid (mud to be used on next hole section). 13.9 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.10 Displacement calculation: 2411' x .0962 bpf= 232 bbls 13.11 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. 13.12 Do not overdisplace by more than 1/2 shoe track volume. Total volume in shoe track is 8.7 bbls. 13.13 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log btwn 6— 18 hours after CIP. Page 21 Revision 0 January, 2015 • • Blossom#1 Drilling & Completion Procedure Flilro�•E) 1,1 C 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 final 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 lkeller@hilcorp.com & cdinger@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Revision 0 January, 2015 • • Blossom#1 Drilling & Completion Procedure Harm p Lid: 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multibowl wellhead assy. Install packoff 10-3/4" P-seals. Test to 3000 psi. 14.3 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. 14.4 Run 4-1/2" BOP test assy, land out test plug (if not installed previously). • Test BOP Pto 250/4000 psi for 5/5 min Test annular to 250/2500 psi.fQr,5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.2 ppg 6% KC1/PHPA drilling fluid for 9-7/8"hole section. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. 14.10 Install 5" liners in mud pumps. • TSM 1000 mud pumps are rated at 4250 psi (85%) /275 gpm (100%) with 5" liners. Page 23 Revision 0 January, 2015 • Blossom#1 Drilling & Completion Procedure Mewl)Ala aka.1,11 15.0 Drill 9-7/8" Hole Section 15.1 Prior to P/U 9-7/8" directional assy, test casing against blind rams to 2600 psi/ 30 min. 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 Bit TFA should be -0.75 -0.80 in2. We need to pump at-450 - 500 gpm to clean the hole effectively. Have the directional driller run hydraulics calculations to confirm optimum TFA. 15.5 P/U the below 9-7/8" directional drilling assy (GR+ RES + Den/Neu LWD) included in below BHA): COMPONENT DATA twin CH) , , O1OTOD OnnOn INNOOt 11m) LAWOOn 'Anna Lona* ��Ae -� - �v/%< On).o�Viiogo. ' "e(Rom rowitectiort, /ilii 1 HODS MM65 PDC 7.000 2.500 9.875 114.43 P 4-112"REG 0.90 2 7'SperryDrill Lobe 7/8-6.0 stg 7.000 4.952 4.952 93.13 B4-1/2"IF 26.40 27.30 3 6-3/4"Float Saab 6.750 2.813 2.813 100.78 B 4-112"IF 2.20 29.50 4 6-314'DIM Collar(Directional) 6.750 3.125 3.155 103.40 B 4-112"IF 9.20 38.70 5 6-3/4'DGR Collar(Gamma) 6.750 1.920 4.430 97.80 B NC 50 4.55 43.25 6 6-314"EWR-P4 Collar(Resistivity) 6.750 2.000 3.978 104.30 B NC 50 12.10 55.36 7 6-3/4"HCIM Collar(Processor) 6.750 1.920 3.667 101.70 B NC 50 4.97 60.33 8 6-3/4"TM Collar(Telemetry) 6.750 3.250 3.551 103.60 B 4-1/2"IF 10.00 70.33 9 6-314'Non Mag Flex Collar 6.750 2.813 100.78 B 4-1/2"IF 30.00 100.33 10 6-3/4"Non Mag Flex Collar 6.750 2.813 100.78 B 4-1/2"IF - 30.00 130.33 • 11 6-3/4'Well Commander Sub 6.750 3.000 3.000 97.86 B 4-1/2"IF 13.00 143.33 12 VO 4.5"IF P x 4.5"CDS 40 B 6.500 2.750 2.750' 92.85 B 4' Q BS 2.75 146.08 13 4 x its 4.5"HWDP 4.500 2.813 33.02 120.00 266.08 14 X/0 4.5"CDS 40 P x 4.5"IF B 6.500 2.750 2.750 92.85 B 4-1/2"IF 2.50 268.58 15 6-1/4"Weatherford Jar 6.250 2.313 2.313 90.24 B 4-1/2"IF 30.00 298.58 16 X/O 4.5"IF P x 4.5"CBS 40 B 6.500 2.188 2.188 100.27 B 4. DS 3.00 301.58 40 17 15 x )ks 4.5"HWDP 4500 2.813 .. _ 33.02 450.00 751.58 Total: 751.58 Page 24 Revision 0 January, 2015 e 9 II Blossom#1 Drilling & Completion Procedure ii Army Ala...1a,u.c 15.6 Primary bit will be the Security 9-7/8" MM65. ivaitly,:',01,i,,::,:.,,FA‘Ntioetaggeirigto.,;§,TTAF'ilr.,1:;•:'10,:iroiiv:::,,:,,I.,!:,..;,0,00,14,:07,- Iterigittete*i,gt,g2t.,,,r,:..,..,..,:„:..:!,..,....-Eliwv.,.....":..,:,:.:5?i,0404 PRODUCT SPECIHCATIONS Cuer,or Type Sok:ereutter MIX Code N4323 . , . ..:,... ,,, •c:... Body Type MATRIX 4f,04*, itilji:.-Ws_Or Total CutWr Count 46 Curter Disicibution lima ilia •x-...- _,P77,....:' 11...t,--- „,,K vope 0 2li --.' 7ii,ii kilrG!'•'-.':WOW Ilii' , ,,,...... — ........,. „.„,. ...._ .... • . , .... Gauge 12 (1 Up[hill 6 (.1 Number or Large.Nonles 6 Number of Medium Nozzles Nurabte of Small Norztes 0 ,ii.- Number of-Micro Nozzles 0 •'"'t, ,G3 is••:, Number of Potts(Sim) 0 Number of Replaceable Ports iSize) 0 `—' 7--.7• '''' -41' ' ' lil Junk Slot Arta Witi itti 16.71 Nommliznit Face Volume 43.4X% API Connection 4-1,2 REG.PIN Recominerstled Mahe-Up Tongue" 12.461—17;766 Hits, Nominal DOT:elisions** Make-Up face to Nose l0.81 in-275 ma Gauge lwitzth 2,3 in-64 man ,0 gti,filet; Sleeve Length Oin-nmin Shoal Diameter 6 ill-132 Hun ill17; 11%, Break Out Plain(Marctit„egaeyo) 1,41054.4400 Approximate Shipping Weight 230Lbs.-113Kg. SPECIAL FEATURES . „ .. ,. Up-Drill CLatcrs on Gov Pods,I?I6-Relieved Gage Material 4771827 9111 specific FeiVITAtmended trinkc,iip torque is,,s.fanciion of Ore bit 1.D.and acnssi hit sub O.D.toi3ind as si,ecifued in API WS Scction A.S.2. ttiwiagri Mmiaimais AT 11.011ilical irrsd nut siay stightly an nuinufacturcti pfado.:.iitaiiittlfratM thin iiibi WO SePlial•ntodtis aro onniAnuously ruvwsved and refuloi Product sffcificatiosri may change wnhout nmicc. G 2013 Rallibucton.All rights reserved.Salts of Halliburton products and services will be in occult/solely with Me aerials and conditions contained in die contract between Halliburton and The eustainel that is applicabk to the salt. :.:::1!.!;:!::.::!: • ;:itiet!!,r;;IIMiti*;11 :.:•.:'!.:.'liti#041411 041410414goi!tilii1:. Page 25 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure Iran„rt,Alaska,T,r,c 15.7 9-7/8" hole section 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. 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: 9.2—9.8 ppg 6% KCI/PHPA fresh water based drilling fluid. Properties: fi'Lud Plastic � MD Weight Viscosity Viscosity Yield Point pH HPHT 2,500'- 9.2—9.8 40-53 15-25 15-25 8.5-9.5 < 11.0 7,500' System Formulation: 6% KCL/EZ MUD/BDF-499 Product << , Concentration Water 0.905 bbl KCI 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 5—10 ppb(3.3 ppb of each) BAROTROL PLUS 2—4 ppb SOLTEX 2—4 ppb BAROID 41 as required for a 9.2—9.8 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.8 TIH, conduct shallow hole test of MWD and confirm LWD functioning properly. 15.9 Continue in hole and tag TOC. Note depth tagged on AM report. 15.10 Drill out plugs and shoe track. Clean out rat hole and drill an additional 20' of new formation. 15.11 CBU and condition mud for FIT. 15.12 Conduct FIT to 12 ppg EMW. Page 26 Revision 0 January, 2015 Blossom#1 Drilling & Completion Procedure Hilcori)Alaska.J I C 15.13 Drill 9-7/8" hole section to 7,500' MD /4,138' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 510 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, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. If tight hole is encountered, screw in and begin backreaming connections until hole conditions improve. Shales in the Beluga formations are notorious for swelling and causing tight hole. Most of the time, backreaming them on a short trip is the only solution. • 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 < 8. • Take MWD surveys every stand drld. Surveys can be taken more frequently if deemed necessary. • Mud Loggers: 30 ft samples with 20' samples in zones of interest, two sets of cuttings, chromatograph, pixler plots. 15.14 Casing point will be determined by hole conditions while drilling from 6500' MD to 7500' MD. 15.15 At TD; pump sweeps, CBU, and pull a wiper trip back to the 10-3/4" shoe. 15.16 TOH with the drilling assy, handle BHA as appropriate. 16.0 Run 7-5/8" Production Casing 16.1 R/U and pull 10" ID wear bushing. Install and test 7-5/8" casing ram in top ram cavity. Test to 250/4000 psi. 16.2 Make a dummy run with casing hanger. Mark landing joint at land out for later reference. 16.3 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 deck prior to running. • Be sure to count the total # of joints on the deck 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. Page 27 Revision 0 January, 2015 a i Blossom#1 Drilling & Completion Procedure p A 16.4 P/U 7-5/8" 29.7# P-110 HC BTC shoe joint, visually verify no debris inside joint. 16.5 Continue M/U &thread locking the shoe track assy consisting of: • (1) Float shoe joint w/ float shoe bucked on. Install (2) bow spring centralizers at 10' from each end over a stop collar. • (1) Baker locked joint. Install (1) centralizer mid tube over a stop collar. • (1) Float collar joint w/float collar bucked on pin end. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float shoe and float collar. 16.6 Run 7-5/8" 29.7# L-80 BTC casing. • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers over couplings on every joint to 7,000' MD. • Install centralizers over couplings on every other joint to 5,100' MD. • Install centralizers over couplings on every 4th joint to 2,500' MD. 16.7 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.8 Slow in and out of slips. 16.9 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 approx 10—20' above TD with hanger landed out. Page 28 Revision 0 January, 2015 • • Blossom#1 Drilling& Completion Procedure 1TBrorp Alaska,ilk 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 L80 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 L80 Coupling Min Yield 80,000 psi Coupling Min Ultimate 95,000 psi Joint Strength 721,000 lbs Internal Pressure Resistance 6,890 psi 7-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 7-5/8" 7,630 ft-lbs 16.10 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.11 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat (slightly) to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.12 Continue circulating until required properties achieved for cmt operations. 16.13 After circulating, lower string and land hanger in wellhead again. Page 29 Revision 0 January, 2015 ! • Blossom#1 Drilling & Completion Procedure nilcorp Alaska?I,I.0 17.0 Cement 7-5/8" Cement Procedure 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. • 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 R/U cmt head (if not already done so). Ensure top & bottom plugs are loaded correctly. 17.3 Pump 5 bbls 10 ppg spacer. Close low torque on plug dropping head, test surface cmt lines to 4000 psi. 17.4 Pump remaining 35 bbls 10 ppg spacer. 17.5 Mix and pump slurry per below calculations: Section: Calculation: Vol (BBLS) Vol(ft3) LEAD: 9-7/8" OH x 7-5/8" csg: (5,100'- 2,000') x .038 bpf x 1.25 = 147.5 827 Total Lead: 147.5 bbls 827 ft3 573 go( TAIL: 2400' x .038 bpf x 1.25 = 114 640 9-7/8" OH x 7-5/8" csg: TAIL: 90' x .046 bpf= 4.1 23 7-5/8" Shoe Track: Total Tail: 118.1 bbls 663 ft3 111 5 V. Page 30 Revision 0 January, 2015 • S Blossom #1 Drilling & Completion Procedure IIileorp Slurry Information �" igI a hli( .r �' 1 F PF, �- _ „, , .i "� ^� '� tit ( �+ . �7,,;• �r E System Conventional Conventional Density 12.4 lb/gal 15.3 lb/gal Yield 1.58 ft3/sk 1.35 ft3/sk Mixed Water 8.09 gal/sk 5.912 gal/sk Mixed Fluid 8.09 gal/sk 5.962 gal/sk Expected Thickening 5:30 HR:MIN 4:00 HR:MIN Expected ISO/API Fluid Loss 13 mL in 30 min Code Description Concentration Code Description Concentration G Cement 94 lb/sk WBWOB G Cement 94 lb/sk WBWOB D110 Retarder 0.05 gal/sk D110 Retarder 0.05 gal/sk VBWOC VBWOC Additives D046 Anti Foam 0.2%BWOB D046 Anti Foam 0.2%BWOB D020 Extender 4.0%BWOB D202 Dispersant 1.5%BWOB D065 Dispersant 0.3%BWOB D400 Gas Control Agent 0.8%BWOB D800 Retarder 0.2%BWOB D154 Extender 8.0%BWOB D174 Expanding Agent 1.5%BWOB 17.7 After pumping cement, drop flexible shut-off plug and displace cement with mud. Use the cement unit to displace with as volumes can be tracked much more accurately. Displacement calcs: • 7,500' x .0459 bpf= 344 bbls. • Displace with 9.2 ppg 6% KC1/PHPA drilling fluid out of mud pits. 17.8 Monitor returns closely while displacing cement. Adjust pump rate if necessary. 17.9 Do not overdisplace by more than '/2 shoe track volume. Total volume in shoe track is 4.1 bbls. 17.10 There should be no cmt returns to surface. TOC is planned to be at 2,000' MD. 17.11 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 final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. Bleed off pressure occasionally as necessary to ensure stage tool isn't opened prematurely. Page 31 Revision 0 January, 2015 i Blossom #1 Drilling & Completion Procedure Iilrorp Alaska,II 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 lkeller(&,hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. 17.1 R/D cement equipment. Flush out wellhead with FW. 17.2 Back out and L/D landing joint, flush out wellhead with FW. 17.3 M/U pack-off running tool and pack-off to bottom of landing joint. Set casing hanger pack-off. Run in lock downs and inject plastic packing element. Test void to 250/3000 psi for 10 min. 17.4 Lay down landing joint and pack-off running tool. 18.0 Drill 6-3/4" Hole Section 18.1 Remove 7-5/8" casing rams from BOP. Install 2-7/8" x 5" VBRs in top cavity. BOP configuration should be (from top down): Annular/VBR/Blind/Mud cross/VBR. 18.2 Test BOPs on 4-1/2" test joint, 18.3 Pull test plug, run and set wear bushing. 18.4 Ensure BHA Components have been inspected previously. 18.5 Ensure to have enough 4" DP in derrick to drill the entire open hole section without having to pick up pipe from the pipeshed. Page 32 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure 1I Ivory Hawke,Li 4 18.6 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 18.7 Ensure TF offset is measured accurately and entered correctly into the MWD software. 18.8 Confirm that the bit is dressed with a TFA of 0.46 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 270 gpm. 18.9 Triple combo LWD will be run in 6-3/4"hole section: • Gamma Ray (DGR: Combined Gamma Ray) • Resistivity (EWR: Shallow/Med/Deep) • Density (DEN: Bulk Density) • Neutron (NEU: Thermal neutron porosity) • Density Image, dip picks, and additional engineer for same. 18.10 P/U below 6-3/4" directional drilling assy: COMPONENT DATA OD 1D Stiff 10 Gauge Length Total Locatio r n yeaDescnpbon i j / y ii "��� � ' 1 HDBS EM65D PDC 4.500 2.250 6.750 40.65 P 3-112"REG 0.60 2 5"SperryDrill Lobe 617-6.0 stg 5.000 3.120 3.120 48.00 B 3-112"IF 23.20 24.00 3 4-314"Float Sub 4.750 2.250 1.000 46.84 B 3-112"IF 2.20 26.20 4 4-314"DM Collar(Directional) 4.750 2.610 2.638 47.00 B 3-112"IF 9.20 35.40 5 4-314 SP4 Collar(Gamma&Resistivity) 4.750 1.250 3.280 48.20 B 3-112"IF 24.57 59.97 6 4-314"ALD Collar(Density) 4.750 1.250 2.696 6.000 45.50 B 3-112"IF 14.35 74.32 67.31 Stabilizer 6.000 67.31 7 4-314"CTN Collar(Porosity) 4.750 1.250 1.853 50.50 B 3-112"IF 11.14 85.46 8 4-314'TM Collar(Telemetry) 4.750; 2.812 3.039 46.10 B 3-112"IF 11.00 96.46 9 4-314'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 2.250III 46.84 B 3-112"IF 30:00 156.46 11 3.5"1FPx4.5"CDS 40B 5.300 2.250 2.250 61.64 64.5"41,2" 2.50 158.96 CDS 40 12 2 x jts 4.5"HWDP 4.500 2.750 41.00 60.00 218.96 13 4.5"CDS 40 P x 3.5"IF B 5.300 2.200 2.250 62.23 8 3-112"IF 2.50 221.46 14 4.75"Weatherford Jar 4.800 2.250 2.250 48.12 8 3-1'2"IF 30.00 251.46 15 3.5" IF P x 4.5"CDS 40 B 5.250 2.250 2.250 60.22 .5"4 4F2" 2 50 253.96 CDS 40 16 17 x jts 4.5"HWDP 4.500 2.750 41.00 510.00 763.96 T 763.96 Page 33 Revision 0 January, 2015 0 • II Blossom #1 Drilling & Completion Procedure filloorls Alaska,11,1„ 18.11 Primary bit will be the Security EM65D: ......,,.„.,„ l''' kts 117.40,144.1LJ,,,,,,Cf4ileee:11&,111111Airtisti7":440101440erttbeltpl:kr,".": ''tV,,sr..." .....'n'tst';.t.e:,:ferttkrr:rt'''"-:' .arfr',..4tyWattortruttrrag*Ifte%-r.,:te*# ,v,„,„,,„,,,,, ;„,,„,„ ,..,„1.,,rf.,i,„,,,,,,,,,,,„,zo ..,,,, ,„,,,,,,,,,„,,c,,,,,,,,,,„,,,„4,,,,,, , „;402§1.0.„,,,oizemf,,,A4igw. .,,„;;,„•.c.eT,,,,,,,,,,,„,,,,,,,Nriate:.5,,,,,,,, .v,:,::, ';:r,9,4„* PRODUCT SPECIFICATIONS Cutter Type- X3-Extreme Drilling .; IA DC Cixie Body Type MATRIX Total Cutter Count "i'l Cutter Distribution Face 4 13 ' kr Gear II ti Up Drill 50 ' "`"-• -".• ''4 ,*s.." Moodier of Large Nozzles Nunn:ter of,Mtedium Nozzles 0 'War Number of Small Nozzles m Nubeorr of Isfiero Nozzks b ll*7 ,,,, ,, Number Number of Replaceable Ports Junk Slot Arcatsq in) tt.e41 Normalized Eike N'roloine :44.69% API Connection 3-1/2 REG.PIN Recommended Make-Up Torque* 5.173-7,&55 Fr*lbs. Ncaninal Dimensions** Make-Up Face w Nose 9.42 in-2,?met Clanue la:nth 2 in-51 Sleeve length 0 M-0 nu Sitatkit Diameter 4_5 in-114 awn limed Out Plate 1Mat..0 i"TtekbaeyN) 1111953144030 Approximate Shipping Weight 90Lbs.-41 Kg. SPECIAL. FEATURES Up-Drill Cutters OD Gage Pads,1;14"Stepped Gage,Optimizted Dual Row-"Li Feature Material#761302 *Bit sNaille resvininiended make-rap tonaur is a banoirni Mild bit ID.and admit bit sub O.D,twiliked as spenifteii in All RP7G Seciatin A **Destan dimenfilerM AM itiViliall And tarry vray diainly nia nausea-edited persiort.Halliburtrin Drill its and Barrier%nvarkls aro eannaudissly reviewed and refined. ervidnet inevirearinsis mid ohatide'.1 inn airline, t°21)13 fialliburton,MI rights resented Saks of lialliburton products and services will be in wand solely with the terms and tsenditiorts contained in the contmt between lialliburtrtn tind the t.1154Ortier thht is applicable to the stile. ;‘tit, riburtWW''5'''''''''''' ,,40'6 patiestiogo*0010.': Page 34 Revision 0 January, 2015 Blossom#1 Drilling & Completion Procedure Miro]p 18.12 TIH to TOC. Shallow test MWD on trip in. Note depth TOC tagged at on AM report. 18.13 Conduct casing test to 3500 psi/ 30 min. 18.14 Drill out shoe track and additional 20' new formation. CBU and prep for FIT. 18.15 Conduct FIT to 12 ppg EMW. 3/k 18.16 9.77/fr'-hole section 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. 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: 9.2 ppg 6%KC1/EZ MUD/BDF-499 fresh water based drilling fluid. Properties: IVIED Weig t Viscosity Viscosity Yield Point pH Min 7,500'- 9.2—9.6 40-53 15-25 15-25 8.5-9.5 < 10.0 11,915' System Formulation: 6% KCL/EZ MUD/BDF-499 Product Concentration Water 0.905 bbl KC1 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) BDF-499 4 ppb EZ MUD DP 0.75 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 9.2—9.6 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) Page 35 Revision 0 January, 2015 • • Blossom#1 Drilling & Completion Procedure Iiikorp Alaska,LLC: 18.17 Drill 6-3/4" hole to 11,915' MD/ 8,283' TVD MD using above motor assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain HTHP fluid loss < 6. • Take MWD surveys every stand drilled. • Mud Loggers: 30 ft samples with 20' samples in zones of interest, two sets of cuttings, chromatograph, pixler plots. 18.18 Hilcorp Geologists will follow LWD log closely to determine exact TD. 18.19 At TD; pump sweeps, CBU, and pull a wiper trip back to the 7-5/8" shoe. 18.20 TOH with drilling assy, handle BHA as appropriate. Drop drift on trip out. Page 36 Revision 0 January, 2015 • • Blossom#1 Drilling & Completion Procedure u,corp AIa.ka,3.1d: 19.0 Run 4-1/2" Production Liner 19.1 M/U and rack cement stand in derrick. • Ensure to drift components prior to M/U. Ensure dart will pass through components. • Confirm largest OD of packer assy will pass through wear bushing. 19.2 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 on the deck prior to running. • Be sure to count the total # of joints on the deck 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. 19.3 P/U shoe joint, visually verify no debris inside joint. 19.4 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). • (1) Joint with landing collar bucked on. • Solid body centralizers will be pre-installed on shoe joint& FC joint. • Install a solid body centralizer on landing collar joint. Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe. 19.5 Continue running 4-1/2" prod liner • 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 to 7,500' MD. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 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 Page 37 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure Alaska,lIC Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWCJC Tubing 4-1/2 in 12.60 Ibift(0271 in) L-80 standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) USA 95,000 Minimum Ultimate Strength(psi) VAM USA 4424 W Sam Houston Pkwy Suite 150 Houston,TX 77041 Pipe Dimensions 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 VAMUSAsatestEraiam-usa corn 0.271 Nominal Wall Thickness(in) 12,60 Nominal Weight(lbsift) 12.25 Plain End Weight(lbs./ft) 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) Connection Dimensions 5.000 Connection 0.a. (in) •-• 3.958 Connection ID.(in) X1-1 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) -0 288,000 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) 017 6,500 Maximum Final Torque(ft-lbs) .011 7,200 Connection Yield Torque (ft-lbs) 19.7 Ensure to run enough liner to provide for approx 200' overlap inside 7-5/8" casing. Ensure hanger/pkr will not be set in a 7-5/8" connection. Page 38 Revision 0 January, 2015 • • Blossom#1 Drilling & Completion Procedure FTilror�i A]nsl.a.LI 19.8 Before picking up Baker ZXP liner hanger/packer assy, count the# of joints on the pipe deck to make sure it coincides with the pipe tally. 19.9 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 19.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 19.11 RIH w/liner on DP no faster than 1-1/2 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 19.12 M/U top drive and fill pipe while lowering string every 10 stands. 19.13 Slow in and out of slips. 19.14 Circulate 1-1/2 drill pipe and liner volume at 7-5/8" shoe prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. Nominal liner hanger setting pressure is 2500 psi. 60% of this value is 1500 psi 19.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 19.16 Continue to fill the DP every stand down using fill up line on rig floor. Do not stop to fill casing. 19.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 19.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure (1500 psi). Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 19.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 39 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure nilrorp Alaska,ii :: 20.0 Cement 4-1/2" Production Liner 20.1 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. • 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. 20.2 Attempt to rotate & reciprocate the liner during cmt operations. This is the most effective method to ensure effective mud and wall cake removal and a good quality cmt bond. 20.3 Pump 5 bbls 10 ppg MUDPUSH II spacer. 20.4 Test surface cmt lines to 4500 psi. 20.5 Pump remaining 15 bbls 12 ppg MUDPUSH II spacer. 20.6 Mix and pump 15.3 ppg class "G" cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess. Section: Calculation: Vol(BELS) Vol (ft3) 7-5/8" x 4-1/2 DP" 200' x 0.026 = 5.2 29 Overlap: 7-5/8" x 4-1/2" Liner 200' x 0.026 = 5.2 29 Overlap: 6-3/4" OH x 4-1/2" Liner: (11,915 —7,500') x 0.025 x 1.5 = 166 932 Shoe Track: 90' x 0.019 = 1.7 9.5 Total Volume: 178.1 bbls ' 1000 ft3 7`f sa Page 40 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure nikoi p Al aka,1,1 Tail Slurry System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk Mix Fluid 5.879 gal/sk Base Fluid 5.879 gal/sk Expected 70 Bc at 5:00 hrs Thickening Code Description Concentration G Cement 94 lb/sk D046 Antifoam 0.2%BWOC D202 Dispersant 1.5% BWOC Additives D400 Gas Control 0.8% BWOC D154 Extender 8.0% BWOC 20.7 Drop DP dart and displace with 9.2 ppg drilling fluid. 20.8 Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point. 20.9 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 20.10 Bump the plug and pressure up as required by Baker procedure to set the liner hanger(20% above nominal setting pressure. 2500 psi is nominal setting pressure. Pressure up to 3000 psi to confirm hanger setting. 20.11 Slack off total liner weight plus 20k to confirm hanger set. 20.12 Do not overdisplace by more than '/2 shoe track. Shoe track volume is 1.7 bbls. 20.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner. 20.14 Bleed pressure to zero to check float equipment. Page 41 Revision 0 January, 2015 • S Blossom #1 Drilling & Completion Procedure Ilii.of p.4I i..i a,Li(` 20.15 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve. 20.16 Rotate slowly and slack off 50k downhole to set the ZXPN liner top packer. 20.17 P/U to P/U weight plus 1 ft. 20.18 Close annular and test 4-1/2" DP x 7-5/8" annulus to 1500 psi / 10 min to test liner top packer. 20.19 Bleed off pressure, open up annular. 20.20 Pressure up to 500 psi down DP and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops off rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 20.21 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 20.22 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 20.23 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 20.24 POOH, verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 20.25 If the HRD-E tool still does not release hydraulically, left-hand(counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 20.26 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 20.27 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 42 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure mem!)Alaska.Li t 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 lkeller d,hilcorp.corn. This will be included with the EOW documentation that goes to the AOGCC. 21.0 Wellbore Clean Up & Displacement 21.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 3.75"bit or mill. • Casing scraper for 4-1/2" 12.6# casing. • +/- 4600' 2-7/8" workstring. • Crossover (No PBR Polish Mills). • Casing scraper for 7-5/8" 29.7# casing. • 4-1/2" DP to surface. 21.2 TIH & clean out well to landing collar(+/- 11,800' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 3-3/4" bit is worked down to the landing collar. • Space out the cleanout BHA so that the 4"bit reaches the 5" landing collar when crossover is +/- 30' above the 5" liner top. • The primary objective of the clean out run is to ensure the TCP assy will reach intended depth. 21.3 After wellbore has been cleaned out satisfactorily using mud, test casing to 3500 psi /30 min. 21.4 Displace drilling fluid in wellbore with a hi-vis pill followed by fresh water. • Consider catching drilling fluid in rain-for-rent tanks for use on a future well if feasible. Page 43 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure H11(11111 Alai.ka,LC,(; • Circulate fresh water into wellbore until clean-up is satisfactory. Do not recirculate fluid, • After a couple circulations using FW, short trip the assy to bring the upper 7-5/8" scraper to surface. • RIH again &tag landing collar w/4" bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by 6%filtered KC1 (or alternative fluid specified by Ops team). 21.5 TOH w/clean out assy. LDDP on the trip out. Note any abnormal wear on the clean out assy. 22.0 Production Tubing Installation and Perf. 23.1 A separate Sundry will be submitted to the AOGCC that will cover the post well logging program/production tubing installation/perforation procedure. Page 44 Revision 0 January, 2015 • • Blossom #1 II Drilling & Completion Procedure Hileorr Alaska.LLC 23.0 BOP Schematic 1I1 2,1 111 111 111 1 4111.- 11"5Mi T-3 Snnrgy OOP ill Ilk Li l i m b. 13-Fnar9y Mock i 6t 191 Manual Manual Manual 11.85' Valvesal., Waive HCR ISI Eat lir tI I1 ,�. Kill . ' �� r01:1- Choke Lite '1' ,fr ; r a1 • Line F "IliWISI/ Ill . rw!se y3__ _ 1A 1601! - V Grade Level Ill Aril Ii! It 5r spool 1.55' 115h1X115M 1I 111 ISI ISI ISI .en anima 5e I i:I HEIS s}skhfr7ii. , +, Yom ' ® 11711111.11111111 .001:P r itY43mxit 5m im t 1 lid ® ® 1 ti 1 1,0 1 -� ;j i : 1. 11D `1 . Page 45 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure Harm',AIa!;ka,1.1A 24.0 Wellhead Schematic EN 1 11 SW X 5-1/19 T c$ 54 EST ie •1 _— Lek "` :,:.:4, ,,,,"elArjAPTEP. , CASING HANGER, ",®jF1A1 i'i7 iMil ii XS— hA 1-i — 1 1 2-1/16 c crmX5.473-s l:�s (� 1E1 17 2 u -2G-LN BOX TOP t 111 1�1 1 a s* 11.1 llii011114 0 sail 01 a , yl , 'l" CAslNAG H MOM filet 11 X 7-6/'611112, 73.7 w ASSEMBLY . EST 4 Ell ■ : Z® 13 1111 MINI MIK II 14) 0 - 41111 4 103/4 1NI.E IBS 11,_ .Mm_..ui u0„„m„..3..... 1 .=. 1117.:.., 40-\\.",2•„1116 541M �� ._' 16-3/4 3M I■1 ill 11.1 CABNG MANGER, SIAB*22 15-3/4 X 10-3j4 ESI a 1 w 11 ill” 1 21/16 SM 16 CNG 10-.3/4 CASNG 7-5/6 CA 2-7/8"Prod Tubing ■ l0,413 PSw lituliEAD ASSEMBLY 16 X 10-3/4 X 7-5/8 A 5-1/2 Via.M a S 7NiS ARE ALT i CAll 1tNg1°' ik.y B850807E0 00N7VEN714.4, D{1CU1uEN7 __--- ____........_ .. m Jnr or moo ;� my t l # ESKIXS 1115 SHOVI I SOU 11E COMM At ' •q" *MON iini no LAP' KB REFERENCE ROWS 01 Y �'r "T a L-,. 1P"-- — �.. �1 . na% - flea. e�y. 4 Page 46 Revision 0 January, 2015 0 • Blossom #1 Drilling & Completion Procedure II Ie p Ala+eka,I,t,t 25.0 Days Vs Depth Days Vs Depth 0 .**.\\ -Blossom 4#1 -5RU 22-22 2 4F'Y#3 z Z. C 4, g 1 #3 ,-. -. • 12000 14000 0 5 10 15 20 25 30 35 40 Days Page 47 Revision 0 January, 2015 • • Blossom #1 Drilling & Completion Procedure rtilrorte 41.3.1a,t,i t: 26.0 Formation Tops ANTICIPATED FORMATION OPS& ZAP EXPECTED intersection Points TOP TOP NAME FLUID MD(FT) TVD(FT) TVDSS(FT) Est.Pressure X Y +/- Surface Locati ,'H i°4H buy 4141, � r., ? ry , 31117' ,3 4 Upper Belu ga et Gas 223' - . 959 2 ;241 ,3-100 Upper Tyonek Target Gas 5,215 -5,000 F 2242 229073 2263303 100 Total Depth 6,300 -6,300 228942 2263755 460 =Primary Objective =Secondary Objective RADIUSTARGET 100 FT 27.0 Anticipated Drilling Hazards 13-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. 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 48 Revision 0 January, 2015 S Blossom #1 Drilling & Completion Procedure IIilcoriz Alzpaka.11 I 9-7/8" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/ flowzan. 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 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme & 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6% KCl 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 (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. ' Page 49 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure Ffilroep Ala3ka.11 C 6-3/4" Hole Section: Lost Circulation: • Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. 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 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 6 m1/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 6% KC1 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. • Do not use "black products"to stabilize coal sections. • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. • No abnormal pressures or temperatures are present in this hole section. Page 50 Revision 0 January, 2015 s •• Blossom#1 Drilling & Completion Procedure [Tarot p Alma IJ,C 28.0 Saxon Rig 169 Layout IRI i air... 'i1 Al— il2 a 3 Y I^ 11.1! . i I n t1..i P t I m limn iy i slln 1� 1 I1v ..• I...iTriIli . 111111111M6' 1111041.2111 rrf li C. �tl!l1111 t '' 1 II O�t�J11 IIIV I Ili Nl Iiia! .iir119 111 i.rCill d?3I ■19IIIEIII6 �' �' . i Ali:,SIE:! Ii1 ,T' j„ imam( ' 1 --"Ift, ,== i pki aim g- U ger 1 �- 1,_,__,,,... .,,,,1 B I �rier'�-• .1.• Illil, ,Ipl a i ,.. III� ��,1� -li 1 1._,,, ,.:,.....,.. .: l ai 0 r. =, = II ��e �l1 Bilis I �� rUIIII rte.. V 9 `� '. 1 fr. L .t r-""" . 1 II i1 1 �.......,�. e �i , 3 rr 1 11Illa)i. .L...r a 111111 III i ' iI i I I' I I II i T Iill1111111 1 I , __ . ..( I Ilii , 'III.1.1 h;, i 'iilll' d Page 51 Revision 0 January, 2015 • Blossom#1 Drilling & Completion Procedure 11 Ic rp Alaska,LCA; 29.0 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 52 Revision 0 January, 2015 0 0 Blossom #1 II Drilling & Completion Procedure RANH p Alaska,Li f 30.0 Choke Manifold Schematic if if, /4- / s' c L e 7 ,, 8714 4.141 43.62 ,. 18 43 1643 — 2 ,41114.41? tit.44 a Is 019 cs.r)r'r -0,0 AR*d - , -11.11 TOM MI 4 d/41/41 141 0 4DMIM4M". , 0 19...14,i6.a411111111 Ole al111111 dmisi a - . it ., . rkv_.-64.4.11 19r !ilalvciai _I .1 MN= 0.10 CP 714 7 84 ilk 0 0 , ill%JL...111111 MIMI °:9 $44 0 1 --,..,--- MOM MIMI 1 IHNIMIN Minn -- .0," zer,71.1, , NIMPIII , 1 2 i, 1412 1144 4) 38 03 4;8 Nu oinzrzum: ci ,d010 4 tr co9. z..-Aiii Ic ,qp: : , 3444 0 144( 11117111 4110 1111111.111111111111 0 iv_1 i !NM M 'Illalif . (1) 742'Gahm me; ,,,, 1 50 a 118: ' 1141; '; / — „ . 6•10 50 N 0 4) ha aichKE mAhhilat (kwl'att .4.4419 —419 419 ON ——aig OPERAT _....., . 62 14.62 1490 1462 431 r/.3.:-...,.., B /4 4352 43 62 I. i 76 i,t4( 67.24 €h .... _ . CAD teml40 1-4 7Wowifr""1——'—4..vaiebillSaw..........ftwok 1.L.47447 14114 R CA5PCZTS W124332,744... 4.':. ''''. „.„, 'C" ;.It;1 GAON ENEROf SONICES 1114.111d 2411...' '1-.* "s .k.) a ...5 T•.... ,,, yja 4 ow r4,741-t,, .... .27- ...,1. .. l- rni...2144*--0,1-04 ...... i Page 53 Revision 0 January, 2015 Blossom #1 Drilling & Completion Procedure HileoiTt 11w-ha. ,IA: 31.0 Casing Design Information Calculation & Casing Design Factors Ninilchik Unit DATE: 1-15-2015 WELL: Blossom#1 FIELD: Niniichik DESIGN BY:Luke Keller Design Criteria: Hole Size 9-7/8' Mud Density: 9.6 ppg Hole Size 6-3/4" Mud Density: 9.6 ppg Hole Size Mud Density: Drilling Mode MASP(sec 2): 1316 psi (see attached MASP determination&calculation) MASP(sec 2,733 psi(see attached MASP determination& calculation) Production Mode MASP: 2,733 psi(see attached MASP determination & calculation) Collapse calculation: Section Calculation 1,2, 3 Normal gradient external stress(0.494 psiift)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 Casing OD 10-314" 7-5/8" 4-112" Top(MD) 0 0 7,300 Top(TVD) 0 0 3,950 Bottom(MD) 2,500 7,500 11,915 Bottom (TVD) 1,574 4,137 8,283 Length 2,500 7,500 4,615 Weight(ppf) 45.5 29.7 12.6 Grade L-80 L-80 L-80 Connection BTC BTC OWC/C HT VI/eight wio Bouyancy Factor(lbs) 113,750 222,750 58,149 Tension at Top of Section(lbs) 113,750 222,750 58,149 Min strength Tension (1000 lbs) 1040 683 288 Worst Case Safety Factor(Tension) 9.14 3.07 4,95 Collapse Pressure at bottom (Psi) 778 2,044 4.092 Collapse Resistance w/o tension(Psi) 2.470 4,790 7,500 Worst Case Safety Factor(Collapse) 3.18 2.34 1.83 MASP(psi) 1.316 2,733 2,733 Minimum Yield(psi) 5.210 6,890 8.430 Worst case safety factor(Burst) 3.96 2.52 3.08 Page 54 Revision 0 January, 2015 ,„„ • Blossom #1 Drilling & Completion Procedure II Ieor1, 1,1a-la,111 32.0 9-7/8" Hole Section MASP fl Maximum Anticipated Surface Pressure Calculation 9-7/8" Hole Section IIti!F°93„ Blossom#1 Ninilchik Unit MD TVD Planned Top: 2500 1574 Planned TD: 7500 4137 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Upper Beluga 2,231 959.33 Gas 8.3 • 0.430 Offset Well Mud Densities Well MW range Top(MD) Bottom (MD) Date Falls Creek 1 10.5- 13.1 2,500 /1,000 1960 Corea Creek 1 9.4-10.4 2,500 6,664 1996 Falls Creek 1 RD 8.7-9,3 3,000 8,332 2001 Falls Creek#5 9.2-9.7 1,758 9,715 2014 Frances#1 9.3 -9,8 2,638 10,703 2014 Falls Creek#6 9.0-9.4 2,424 9,060 2014 Assumptions: 1. Fracture gradient at 2,500MD/ 1,574'TVD is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8" hole section is 9.6 ppg. 3. Calculations assume"Unknown" reservoir contains 100%gas(worst case). Fracture Pressure at 10-3/4"shoe considering a full column of gas from shoe to surface: 1574 (ft)x 0.936{psi/ft)= 1473 psi 1473(psi)- 10.1{psi/ft)*1574(ft)1= 1316 psi MASP from pore pressure(unknown gas sand at TD,at 8.3 ppg) 4,137(ft)x 0.43(psi/ft)= 1779 psi 1779(psi)- [0.1(psi/ft)*4137(ft)1= 1366 psi • Summary: 1. MASP while drilling 9-7/8" intermediate hole is governed by fracture gradient at the 10-3/4'casing shoe Page 55 Revision 0 January, 2015 I 0 Blossom #1 Drilling & Completion Procedure Mena I)Alaska,LI A' 33.0 6-3/4" Hole Section MASP El Maximum Anticipated Surface Pressure Calculation 6-3/4''Hole Section !filt;(9?. Blossom#1 Cook Inlet,Alaska MD TVD Planned Top: 7500 4137 Planned TD: 11915 8283 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad , . Upper Tyonek Target 5,215 ' I 2242 • f Oil/Gas/Wet I 8.3 0.430 Offset Well Mud Densities Well MW range Top(MD) Bottom(MD) Date Falls Creek 1 12.2-12.3 11,000 I 13,500 1960 — ....._ Corea Creek 1 9.4- 10.4 2,500 6,664 1996 Falls Creek 1 RD 8.7-9.3 3 8,332 2001 . .„ 000 . .. Falls Creek#5 9.2 -9.7 1,758 9,715 2014 Frances#1 9.5 -9,7 10,700 12,814 2014 Falls Creek#6 9.0-9.4 2,424 9,060 2014 Assumptions: 1. Fracture gradient at 7,500MD/4,137 TVD is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 9-7/8" hole section is 9.6 ppg. 3. Calculations assume"Unknown" reservoir contains 100%gas(worst case). Fracture Pressure at 7-5/8''shoe considering a full column of gas from shoe to surface: 4,137 (ft)x 0.936(psi/ft)= 3872 psi _. 3,872 (psi) -[0.1(psi/ft)*4,137(ft)1= 3459 psi MASP MASP from pore pressure(entire wellbore evacuated to gas from TD) 8,283(ft)x 0.43(psi/ft)= 3,561 psi ci \3,561(psi)- [0.1(psigt)*8,283 (ft)1= 2733 psi --- --...---___ Summary: 1. MASP while drilling 6-3/4" production hole is governed by SIBHP minus gas gradient(0.1 psi/ft)to surface V after entire wellbore is evacuated to gas. Page 56 Revision 0 January, 2015 • 0 Blossom #1 Drilling & Completion Procedure ntiro'iv.tLi.ha,t,cr: 34.0 Spider Plot (NAD 27) (Governmental Sections) Legend a1 - - XVI g . Sa.trtaz.a t g° � $1�+ Sant 1131 • cxr,..Eat sn woie€ anw o - ',Id."N PmtPts 9 Kpg Parces Cil atx3 bus€lett Bidaty+ P iNIL HI UNIT °., A3L389737 °S001 VO INOI3 is S P ' i 6. 1 a.».. Io ,' =I [PEI m LP # .M d e v i Q r a 0 i ' 6 fl 1 aP A02439'9 9 P R ,4� 1 f 5 L 1 i ��I� [}31 s 1 SI 1.1'4 , 5 _ 5 �F 5 IkAa N 4 4 Ninilchik Unit Feet 2 000 a9ru p titt,14,Ill /�y�+ ry� I Blossom Almsba Stale Plane Zotto 4,liAD27 A Map Daba:1/132015 Page 57 Revision 0 January, 2015 • Blossom #1 Drilling & Completion Procedure HiIcor!) 11a..I.a.1,I,C. 35.0 Surface Plat (As Built) (NAD 27) 1 373 T. 4I SECTION 14 T1N R13VV " FEL , SECTION 13 T1N R13W 1 I BLOSSOM#1 WELL AS-STAKED NAD27 ASP ZONE 4 I N: 2258334.36' 1 E: 231717.27' i I LAT: 60° 10'24.6288"N LON: 151° 28' 24.0745"W b—1 an rn I W :Z W3 ELEV= 215.0" NGVD29 -"- 17'5 SECTION 14 TIN, R13W, AK 11)- 1155.0' FSL, 373.7' FEL . ..-, I I I SECTION LINE a . ___ SECTNDP4LtIE •••••••• • ••••111.-1-“mill••=1111....1.1.•• •1. SECTION 23 T1N R 13W . SECTION 24 TIN R13W ..-„st- _A_: „t ,, :* itiW ,*. 0 .. , f ....s.‘ • NOTES 1 BASIS OF GEotihroL.:CONTROL AND NAD83 POSITION(EPOC*I "is '1 01,14.•• .:.--. 2033}IS AN OPUS SOLUTION FROM NGS STATIOP4S'KENS CURS ir ''''' ARV 'ZAN1 CCS ARP".AND'TSEA ARV TO ESTABLISH THE III % POSITION OF NGS CONTROL STATION PAT 1979 RAI 1 THE 1%111.Vek.' GEODETIC POSITION OF PAT 1979 RM 1 WAS DETERMINED TO HAVE A LATITUDE OF 60'69'48 70932'N AND A LONGITUDE OF 151'2927 84313TW THE ALASKA STATE PLANE COORDINATES(ASP) i - .._• -.E..--.- ... ..... ZONE 4 MAO B3 FEET ARE N.2,2E4,726.735 E.-1368 837 058 WIN ELEV In 40LNGVD29I . .•,..... ...„aria -- 2 SECTION LINES SHOwN WERE ESTABLISHED FROM SURVEY —4— TIES TO ORIGINAL.OO MONLINIENTATION 0967) SCALE 3, DATA TRANSFORMATIONS(NADO3 TO NAOZT ASPZ46 WERE I . 1 FT„i7, , I DONE USING CORPSCON VERSION 6 0 1 BLOSSOM #1 WELL AS-STAKED SURFACE LOCATION (NAD27) 11::11 'LOCATION:SECTION 14. TOWNSHIP 1 NORTH, 7 _ ENGINEERING-TESTING MAPPING MeLA14,, SOLOOTNA,Ax 96609 VOICE 007)2fa-via FAX (907)283.3285 .. BYRANGE 13 WEST,SEWARD MERIDIAN ALASKA SURVEYINGG- JOB NO, 143154 --- Ilileorp Alaska.Lk REV. - Cormitibil lac www MICLANECG COM I BGB Date-12/10/14 FIGURE: 1 Page 58 Revision 0 January, 2015 0 0 Blossom#1 Drilling & Completion Procedure tide.p ala.«ka,LI( 36.0 Offset MW vs TVD Chart MW vs TVA Offsets 0 k --Corea Creek#1(1996) 1000 -°� °.° Fa s Creek#5(2014) �°—'GO#1(2 ) Nkit:i'' _Z000 ' � - e GCS#2(2001) r IP30)0 400 011//a 5000 g E ,\ 0 i 7000 ? I M00 } I k I 9000 \ .... 10000 E 11000 8 9 10 11 12 13 14 15 Mud Weight(PPG) Page 59 Revision 0 January, 2015 i i II Blossom#1 Drilling & Completion Procedure Hdew p Alaska,LI.I 37.0 Drill Pipe Information 57.,E 4 1/2" r� WEIGI-Pr; 16.8 LaS/Fr ESLQMMICO GRADE 5.135 RANGE 11(31.5' DRILL PIPE SPECS CONNECTION; cos,* TUBE NEW PREMIUM IN MM EN MM OD 4.500 114.31 4,365 110.9 WALL THICKNESS I 0.337 8.6q 0.270 6.8 IDI 3.826 97.2. a826 97.2 r-LBS I444 rr s I,4-14 TORSIONAL STRENGTH$ 55,453 75.200 43,451 58.900 80%TORSIONAL STRENGTH 44,362 60.200 34,761 47.100 LHS DAN LHS DAN TENSILE STRENGTH 595,004 265,300 468,297 208,800 PSI KPA PSI KPA INTERNAL PRESSURE CAPACITY 17,693 121,985 16,176 111,530 COLLAPSE CAPACITY 16,769 115,615 10,959 75.561 IN2 MM2 IN2 MM2 CROSS SECTIONAL AREA D00. 4.407 2844 3,469 2238 CROSS SECTIONAL AREA OD 15.304 10261 , 14,966 9655 CROSS SECTIONAL AREA ID; 11497 7417 11.497 7417' ' INS' MM2 IN* MM2 SECTION MODt1I „ISI 4.271 69995! -3.347 54845 POLAR SECTION MODULUS' 8.543 139989 6.694 109690 TOOL.JOINT NEW I) PREMIUM PSI KPA PSI KPA YIELD STRENGTH' 130,000 896,318 130,000 8.96,318 IN MM EN MM OD 5.2500 133 4 5.1 198 130.0 ID 2.6875 68.3 2.6875 68.3 PIN LENGTH 1 1,0 279.4 1 1.0 279.4, Box LENGTH 14,0 355.6 14.0 355.6 FFLEI,S N-M FT-LEIS NM TORSIONAL STRENGTH 35.400 48.000 34,700 47,100 MAX MAKE-UP TORQUE 22,500 30.500 21.400 29.000 RECOMMENDED MAKE-UP TORQUE'' 21,200 28,800 20,800 28.200 MIN MAKE-UP TORQUE 19,600 26,600 19,300 26.200 LBS DAN LBS DAN TENSILE STRENGTH, 824,400 367,600 804,900 358,900 TOOL JOINT/DRILL PIPE TORSIONAL RATIO 0.64 0.80 DRILL PIPE ASSEMBLY WITH CONNECTION ESSIFT KG/M ADJUSTED WEIGHT 17.67 26,64 FT M APPROXIMATE LENGTH 31,50 9,60 GAL/FT M2fM FLUID DISPLACEMENT 0.273 0,003394 FLUID CAPACITY 0.577 0.007 169 IN MM DRIFT SIZE; 2.5625 65 Page 60 Revision 0 January, 2015 / ✓ ; I ure I Rlosso--m*1 Procedure - Drilling & Completion .., 0 cDS4 1:11[ ,., -4.,11.: DRILL PIPE WITH EiFT 'OgleMNINI,3-15VAIII10!!!!: .43 I-B .i.kI ....... . .,s 135 16.s ,-„,„,,".16:00111111011411141i0,1,11111**40;101116111 A 2' • F.c.TIoN ..---,,,, 01,,iirolliklilik.E1'4..11111101411111:1 .,,,Ain*"." 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Rev Page 61 ision 0 January, 2015 i Hilcorp Energy Company Ninilchik Unit Blossom Blossom #1 Blossom #1 Plan: Blossom #1 wp3.b Standard Proposal Report 08 January, 2015 11 HALLIBURTON Sperry Drilling Services HALLIBURTON Project: Ninilchik Unit DETAILS Blossom 81 NAD 1927(NADCON OONUS) Alaska Zone 04 Spore,"Orating - Site: Blossom Ground Level: 215.00 Well: Blossom #1 +N/-S 00/-W Noting Faring Lotittude Longitude Sloe Wellbore: Blossom #1 000 0.00 2258334.36 231717.27 60°10'24,63 N 151°28'24.07W Design: Blossom#1 wp3-b -750 4 - Start Build 3.00 0 - Start DLS 5.00 TFO-0.26 Start 3361.70 hold at 1693.08 MD 500 750— 16 po O _ ,SSo Start DLS 5.00 TFO 177.20 ' N yij 0 0 1500— N n o0 n? o _ 10 3/4" a h- 00 2250— /. 4'h.... a Start 2400.00 hold at 5904.15 MD C- 3000— o - 65) o - Blossom 1-Beluga T-1 toll o _ - 1p00 .-3750— . c - 15p0 Start DLS 3.00 TFO 140.33 4500— 6000 ' d - h -- „7 5/6" f"52502..Beluga 135 _ Blossom 1-Tyonek T-1 g t t-- Start 986.08 hold at 8501.04 MD Tyonek T-1 5000 Start 400.00 hold at 9487.12 MD 6000— 903- 1-8 ..... ....... ........ ._._. ...- ..... _._.. -- p-------TD at 9887.12 _ Blossom 1-BI-IL tgt 6750— 0 1050 11000 7500— '053° - T-60 8250— _. ..._........_._. --'Oj1916 3b _`\T-65 5..Liner g\ossott\lit WP -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 4.'13500 Vertical Section at 343.03°(1500 usft/in) lileorp HAt.LIDUFtT0N Project: Ninilchik Unit Site: Blossom Well: Blossom #1 WELL DETAILS: Blossom#1 Gronnd Level: 215.00 °''O o�:utngt +N/-S +E/-W Northing Fasting Latittude Longitude Slot p. Wellbore: Blossom #1 0.00 0.00 2258334.36 231717.27 60°10'24.63 N 151°28'24.07 W Plan: Blossom#1 wp3.b REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Blossom#1,True North Vertical(TVD)Reference:Plan:Blossom#1©233.00usft(Saxon 169(215'GL+18'DF)) Measured Depth Reference: Plan:Blossom#1 81 233.00usft(Saxon 169(215'GL+18'OF)) 6250- .9p3b Calculation Method:Minimum Curvature - d� B\°'sore a25° 6000- 5"Liner. 13Sp 5750- 17.5p 5500- 6150 TD at 9887.12 -- Blossom 1-BHI,tgtl �y50 _ Start 400.00 hold at 9487.12 MD 5250- 185%conf.l Start 986.08 hold at 8501.04 MD 519 5000 Blossom 1-Tyonek T-1 tgt _ -7518 - __Start DIS 3.00 TFO 140.33 -- 185%conf 4750--1J 550 App° 4500- )5p0 Start 2400.00 hold at 5904.15 MD 4250- 5000 4000 l Blossom 1-Beluga T-1 tgt wp3b 3750- - Start DLS 5.00 TFO 177.20 2 Sp - C 3500- lBlossom 1-Beluga T-1 tgt 0 3250- t-• 3000- 0 2750- 'tippy rn 2500- 10 3/4" 2250- .51 2000- _ `1So 1750 H. 1500- 1250- -_ \5° Start 3361.70 hold at 1693.08 MD 1000 750- 500 H <ti5p M Azimuths to True North Start DLS 5.00 TFO-0.26 250- Magnetic North:16.52° `poo Magnetic Field �gp Strength:55205.4snT ' 0- Dip Angle:73.16° 250- Start Build 3.00 Date:2/23/2015 Model:BGGM2014 -250- -4250 250- -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 West(-)/East(+)(750 usft/in) • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM NORTH US+CANADA Local Co-ordinate Reference: Well Blossom#1 Company: Hilcorp Energy Company ND Reference: Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Project: Ninilchik Unit MD Reference: Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Site: Blossom North Reference: True Well; Blossom#1 Survey Calculation Method: Minimum Curvature Wellbore: Blossom#1 Design: Blossom#1 wp3.b Project Ninilchik 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 Using geodetic scale factor _ Site Blossom Site Position: Northing: 2,258,094.00 usft Latitude: 60°10'22.21 N From: Map Easting: 231,462.00 usft Longitude: 151°28'29.01W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.28 ° Well Blossom#1 3R Well Position +N/-S 0.00 usft Northing: 2,258,334.36 usft Latitude: 60°10'24.63 N +El-W 0.00 usft Easting: 231,717.27 usft Longitude: 151°28'24.07 WI Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 215.00 usft J Wellbore Blossom#1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 2/23/2015 16.52 73.18 55,205 Design Blossom#1 wp3.b Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(ND) +N/-S' +EI-W Direction K tl' (usft) ((lsft)' lusft) (°), 18.00 0.00 0.00 343.03 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face UF (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) ,,,-,'!"-'k-'''',1";',1','7'''.:" 18.00 0.00 0.00 18.00 -215.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 17.00 0.00 0.00 0.00 0.00 0.00 0.00 350.00 3.00 330.00 349.95 116.95 2.27 -1.31 3.00 3.00 0.00 330.00 1,800.41 75.52 329.46 1,399.50 1,166.50 741.30 436.85 5.00 5.00 0.04 -0.55 5,046.86 75.52 329.46 2,211.23 1,978.23 3,448.56 -2,034.12 0.00 0.00 0.00 0.00 5,132.38 75.00 333.85 2,233.00 2,000.00 3,521.33 -2,073.38 5.00 -0.61 5.13 97.55 6,229,64 20.17 336.69 2,945.26 2,712.26 4,225.34 -2,407.74 5.00 -5.00 0.26 178.80 9,805.58 20.17 336.69 6,302.00 6,069.00 5,357.48 -2,895.56 0.00 0.00 0.00 0.00 11,915.95 20.17 336.69 8,283.00 8,050.00 6,025.61 -3,183.45 0.00 0.00 0.00 0.00 1/8/2015 12:27:11PM Page 2 COMPASS 5000.1 Build 70 0 • Halliburton 1-IALLIBIJRT'OPJ Standard Proposal Report �< Sperry EDM-NORTH US+CANADA ,: ,z Well Blossom#1 Vis_ Company:°` Hilcorp Energy Company � � _ - � Plan:Blossom#1 @ 233.O0usft(Saxon 169(215'GL+ Project: Ninilchik Unit @ Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Site: Blossom North Reference: True Well: Blossom#1 Survey Calculation Method: Minimum Curvature Wellbore: Blossom#1 Design: Blossom#1 wp3.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss' +N/-S +EI-W Northing Basting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -215.00 18.00 0.00 0.00 18.00 -215.00 0.00 0.00 2,258,334.36 231,717.27 0.00 0.00 100.00 0.00 0.00 100.00 -133.00 0.00 0.00 2,258,334.36 231,717.27 0.00 0.00 200.00 0.00 0.00 200.00 -33.00 0.00 0.00 2,258,334.36 231,717.27 0.00 0.00 250.00 0.00 0.00 250.00 17.00 0.00 0.00 2,258,334.36 231,717.27 0.00 0.00 Start Build 3.00 300.00 1.50 330.00 299.99 66.99 0.57 -0.33 2,258,334.93 231,716.96 3.00 0.64 350.00 3.00 330.00 349.95 116.95 2.27 -1.31 2,258,336.66 231,716.01 3.00 2.55 370.00 4.00 329.86 369.92 136.92 3.32 -1.92 2,258,337.73 231,715.42 5.00 3.74 Start DLS 5.00 TFO-0.26 400.00 5.50 329.75 399.81 166.81 5.47 -3.17 2,258,339.90 231,714.22 5.00 6.16 500.00 10.50 329.61 498.81 265.81 17.48 -10.20 2,258,352.06 231,707.46 5.00 19.69 600.00 15.50 329.56 596.21 363.21 36.87 -21.59 2,258,371.70 231,696.51 5.00 41.56 700.00 20.50 329.53 691.29 458.29 63.50 -37.25 2,258,398.67 231,681.45 5.00 71.60 800.00 25.50 329.51 783.31 550.31 97.16 -57.06 2,258,432.77 231,662.39 5.00 109.58 900.00 30.50 329.50 871.58 638.58 137.60 -80.87 2,258,473.73 231,639.49 5.00 155.21 1,000.00 35.50 329.49 955.42 722.42 184.51 -108.51 2,258,521.24 231,612.90 5.00 208.15 1,100.00 40.50 329.49 1,034.19 801.19 237.54 -139.76 2,258,574.95 231,582.85 5.00 267.98 1,200.00 45.50 329.48 1,107.31 874.31 296.27 -174.38 2,258,634.44 231,549.55 5.00 334.26 1,300.00 50.50 329.48 1,174.20 941.20 360.27 -212.11 2,258,699.26 231,513.25 5.00 406.49 1,400.00 55.50 329.47 1,234.36 1,001.36 429.04 -252.66 2,258,768.92 231,474.25 5.00 484.10 1,500.00 60.50 329.47 1,287.34 1,054.34 502.06 -295.73 2,258,842.89 231,432.82 5.00 566.52 1,600.00 65.50 329.47 1,332.72 1,099.72 578.78 -340.98 2,258,920.60 231,389.29 5.00 653.10 1,693.08 70.15 329.46 1,367.84 1,134.84 653.01 -384.76 2,258,995.78 231,347.18 5.00 736.88 Start 3361.70 hold at 1693.08 MD 1,700.00 70.50 329.46 1,370.17 1,137.17 658.62 -388.07 2,259,001.46 231,343.99 5.00 743.21 1,800.41 75.52 329.46 1,399.50 1,166.50 741.30 -436.85 2,259,085.21 231,297.07 5.00 836.52 1,900.00 75.52 329.46 1,424.40 1,191.40 824.35 -485.85 2,259,169.33 231,249.94 0.00 930.26 2,000.00 75.52 329.46 1,449.41 1,216.41 907.74 -535.05 2,259,253.79 231,202.61 0.00 1,024.38 2,100.00 75.52 329.46 1,474.41 1,241.41 991.13 -584.25 2,259,338.26 231,155.29 0.00 1,118.50 2,200.00 75.52 329.46 1,499.41 1,266.41 1,074.52 -633.45 2,259,422.73 231,107.96 0.00 1,212.62 2,300.00 75.52 329.46 1,524.42 1,291.42 1,157.91 -682.65 2,259,507.19 231,060.63 0.00 1,306.74 2,400.00 75.52 329.46 1,549.42 1,316.42 1,241.31 -731.85 2,259,591.66 231,013.31 0.00 1,400.86 2,500.00 75.52 329.46 1,574.42 1,341.42 1,324.70 -781.05 2,259,676.13 230,965.98 0.00 1,494.98 2,600.00 75.52 329.46 1,599.43 1,366.43 1,408.09 -830.25 2,259,760.59 230,918.65 0.00 1,589.10 2,700.00 75.52 329.46 1,624.43 1,391.43 1,491.48 -879.45 2,259,845.06 230,871.32 0.00 1,683.22 2,800.00 75.52 329.46 1,649.44 1,416.44 1,574.87 -928.65 2,259,929.53 230,824.00 0.00 1,777.34 2,900.00 75.52 329.46 1,674.44 1,441.44 1,658.26 -977.85 2,260,013.99 230,776.67 0.00 1,871.47 3,000.00 75.52 329.46 1,699.44 1,466.44 1,741.65 -1,027.05 2,260,098.46 230,729.34 0.00 1,965.59 3,100.00 75.52 329.46 1,724.45 1,491.45 1,825.05 -1,076.25 2,260,182.93 230,682.02 0.00 2,059.71 3,200.00 75.52 329.46 1,749.45 1,516.45 1,908.44 -1,125.45 2,260,267.39 230,634.69 0.00 2,153.83 3,300.00 75.52 329.46 1,774.45 1,541.45 1,991.83 -1,174.66 2,260,351.86 230,587.36 0.00 2,247.95 3,400.00 75.52 329.46 1,799.46 1,566.46 2,075.22 -1,223.86 2,260,436.33 230,540.04 0.00 2,342.07 3,500.00 75.52 329.46 1,824.46 1,591.46 2,158.61 -1,273.06 2,260,520.79 230,492.71 0.00 2,436.19 3,600.00 75.52 329.46 1,849.46 1,616.46 2,242.00 -1,322.26 2,260,605.26 230,445.38 0.00 2,530.31 3,700.00 75.52 329.46 1,874.47 1,641.47 2,325.39 -1,371.46 2,260,689.73 230,398.05 0.00 2,624.43 1/8/2015 12:27:11PM Page 3 COMPASS 5000.1 Build 70 • • Halliburton Standard Proposal Report „,,,, ,, „. ___ . .... „tea ,. ,.�. Database: Sperry EDM-NORTH US+CANADA Local Co Well Blossom#1 Company: Hilcorp Energy Company TVD Referen Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+' Project: Ninilchik Unit MD Reference: PIan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Site: Blossom North Reference: True Well: Blossom#1 Survey Calculation Method: Minimum Curvature Wellbore: Blossom#1 Design: Blossom#1 wp3.b Planned Survey I 1 I I 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) 1,666.47 3,800.00 75.52 329.46 1,899.47 1,666.47 2,408.79 -1,420.66 2,260,774.20 230,350.73 0.00 2,718.55 3,900.00 75,52 329.46 1,924.48 1,691.48 2,492.18 -1,469.86 2,260,858.66 230,303.40 0.00 2,812.67 4,000.00 75.52 329.46 1,949.48 1,716.48 2,575.57 -1,519.06 2,260,943.13 230,256.07 0.00 2,906.79 4,100.00 75.52 329.46 1,974.48 1,741.48 2,658.96 -1,568.26 2,261,027.60 230,208.75 0.00 3,000.91 4,200.00 75.52 329.46 1,999.49 1,766.49 2,742.35 -1,617.46 2,261,112.06 230,161.42 0.00 3,095.03 4,202.06 75.52 329.46 2,000.00 1,767.00 2,744.07 -1,618.47 2,261,113.80 230,160.45 0.00 3,096.97 10 3/4' 4,300.00 75.52 329.46 2,024.49 1,791.49 2,825.74 -1,666.66 2,261,196.53 230,114.09 0.00 3,189.15 4,400.00 75.52 329.46 2,049.49 1,816.49 2,909.13 -1,715.86 2,261,281.00 230,066.77 0.00 3,283.27 4,500.00 75.52 329.46 2,074.50 1,841.50 2,992.53 -1,765.06 2,261,365.46 230,019.44 0.00 3,377.40 4,600.00 75.52 329.46 2,099.50 1,866.50 3,075.92 -1,814.26 2,261,449.93 229,972.11 0.00 3,471.52 4,700.00 75.52 329.46 2,124.50 1,891.50 3,159.31 -1,863.46 2,261,534.40 229,924.78 0.00 3,565.64 4,800.00 75.52 329.46 2,149.51 1,916.51 3,242.70 -1,912.66 2,261,618.86 229,877.46 0.00 3,659.76 4,900.00 75.52 329.46 2,174.51 1,941.51 3,326.09 -1,961.86 2,261,703.33 229,830.13 0.00 3,753.88 5,000.00 75.52 329.46 2,199.51 1,966.51 3,409.48 -2,011.06 2,261,787.80 229,782.80 0.00 3,848.00 5,046.86 75.52 329.46 2,211.23 1,978.23 3,448.56 -2,034.12 2,261,827.38 229,760.62 0.00 3,892.11 5,054.79 75.47 329.87 2,213.22 1,980.22 3,455.18 -2,037.99 2,261,834.09 229,756.90 5.00 3,899.57 Start DLS 5.00 TFO 177.20 5,100.00 75.19 332.18 2,224.67 1,991.67 3,493.44 -2,059.18 2,261,872.81 229,736.57 5.00 3,942.35 5,132.38 75.00 333.85 2,233.00 2,000.00 3,521.33 -2,073.38 2,261,901.00 229,723.00 5.00 3,973.16 Blossom 1-Beluga T-1 tgt 5,200.00 71.62 333.92 2,252.42 2,019.42 3,579.48 -2,101.88 2,261,959.77 229,695.80 5.00 4,037.10 5,300.00 66.62 334.04 2,288.05 2,055.05 3,663.41 -2,142.86 2,262,044.60 229,656.71 5.00 4,129.34 5,400.00 61.62 334.16 2,331.68 2,098.68 3,744.32 -2,182.15 2,262,126.36 229,619.23 5.00 4,218.19 5,500.00 56.62 334.30 2,382.98 2,149.98 3,821.59 -2,219.45 2,262,204.44 229,583.66 5.00 4,302.98 5,600.00 51.63 334.45 2,441.57 2,208.57 3,894.63 -2,254.48 2,262,278.24 229,550.27 5.00 4,383.06 5,700.00 46.63 334.63 2,506.99 2,273.99 3,962.88 -2,286.98 2,262,347.20 229,519.31 5.00 4,457.83 5,742.23 44.52 334.71 2,536.55 2,303.55 3,990.13 -2,299.88 2,262,374.73 229,507.02 5.00 4,487.66 Blossom 1-Beluga T-1 tgt wp3b 5,800.00 41.63 334.84 2,578.74 2,345.74 4,025.82 -2,316.69 2,262,410.79 229,491.01 5.00 4,526.70 5,900.00 36.63 335.09 2,656.29 2,423.29 4,082.98 -2,343.39 2,262,468.52 229,465.59 5.00 4,589.16 5,904.15 36.42 335.11 2,659.62 2,426.62 4,085.22 -2,344.43 2,262,470.79 229,464.60 5.00 4,591.61 Start 2400.00 hold at 5904.15 MD 6,000.00 31.63 335.42 2,739.04 2,506.04 4,133.92 -2,366.88 2,262,519.97 229,443.24 5.00 4,644.74 6,100.00 26.64 335.84 2,826.36 2,593.36 4,178.25 -2,386.98 2,262,564.74 229,424.14 5.00 4,693.01 6,200.00 21.65 336.45 2,917.58 2,684.58 4,215.64 -2,403.53 2,262,602.49 229,408.42 5.00 4,733.60 6,229.64 20.17 336.69 2,945.26 2,712.26 4,225.34 -2,407.74 2,262,612.28 229,404.44 5.00 4,744.11 6,300.00 20.17 336.69 3,011.31 2,778.31 4,247.61 -2,417.34 2,262,634.77 229,395.34 0.00 4,768.21 6,400.00 20.17 336.69 3,105.18 2,872.18 4,279.27 -2,430.98 2,262,666.72 229,382.40 0.00 4,802.48 6,500.00 20.17 336.69 3,199.05 2,966.05 4,310.93 -2,444.62 2,262,698.68 229,369.47 0.00 4,836.74 6,600.00 20.17 336.69 3,292.92 3,059.92 4,342.59 -2,458.26 2,262,730.63 229,356.54 0.00 4,871.00 6,700.00 20.17 336.69 3,386.79 3,153.79 4,374.25 -2,471.90 2,262,762.59 229,343.61 0.00 4,905.27 6,800.00 20.17 336.69 3,480.66 3,247.66 4,405.91 -2,485.54 2,262,794.55 229,330.68 0.00 4,939.53 6,900.00 20.17 336.69 3,574.53 3,341.53 4,437.57 -2,499.19 2,262,826.50 229,317.75 0.00 4,973.79 7,000.00 20.17 336.69 3,668.40 3,435.40 4,469.23 -2,512.83 2,262,858.46 229,304.81 0.00 5,008.06 1/8/2015 12:27:11 PM Page 4 COMPASS 5000.1 Build 70 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Blossom#1 Company: Hilcorp Energy Company TVD Reference: Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Project: Ninilchik Unit MD Reference: Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Site: Blossom North Reference: a; 7 True Well: Blossom#1 iuryay catculatiO Me Minimum Curvature Wellbore: Blossom#1c t Design: Blossom#1 wp3.b < ., Planned Survey :70,+ ' mi, +T-7- Vertical Map s`,: �''' Map -' ���' Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,529.27 7,100.00 20.17 336.69 3,762.27 3,529.27 4,500.89 -2,526.47 2,262,890.41 229,291.88 0.00 5,042.32 7,200.00 20.17 336.69 3,856.14 3,623.14 4,532.55 -2,540.11 2,262,922.37 229,278.95 0.00 5,076.58 7,300.00 20.17 336.69 3,950.01 3,717.01 4,564.21 -2,553.75 2,262,954.32 229,266.02 0.00 5,110.84 7,400.00 20.17 336.69 4,043.88 3,810.88 4,595.87 -2,567.39 2,262,986.28 229,253.09 0.00 5,145.11 7,500.00 20.17 336.69 4,137.75 3,904.75 4,627.53 -2,581.04 2,263,018.24 229,240.15 0.00 5,179.37 7,600.00 20.17 336.69 4,231.62 3,998.62 4,659.19 -2,594.68 2,263,050.19 229,227.22 0.00 5,213.63 7,700.00 20.17 336.69 4,325.49 4,092.49 4,690.85 -2,608.32 2,263,082.15 229,214.29 0.00 5,247.90 7,800.00 20.17 336.69 4,419.36 4,186.36 4,722.51 -2,621.96 2,263,114.10 229,201.36 0.00 5,282.16 7,900.00 20.17 336.69 4,513.23 4,280.23 4,754.17 -2,635.60 2,263,146.06 229,188.43 0.00 5,316.42 8,000.00 20.17 336.69 4,607.10 4,374.10 4,785.83 -2,649.25 2,263,178.01 229,175.50 0.00 5,350.68 8,100.00 20.17 336.69 4,700.97 4,467.97 4,817.49 -2,662.89 2,263,209.97 229,162.56 0.00 5,384.95 8,200.00 20.17 336.69 4,794.84 4,561.84 4,849.15 -2,676.53 2,263,241.93 229,149.63 0.00 5,419.21 8,300.00 20.17 336.69 4,888.71 4,655.71 4,880.81 -2,690.17 2,263,273.88 229,136.70 0.00 5,453.47 8,304.15 20.17 336.69 4,892.61 4,659.61 4,882.13 -2,690.74 2,263,275.21 229,136.16 0.00 5,454.90 Start DLS 3.00 TFO 140.33 8,400.00 20.17 336.69 4,982.58 4,749.58 4,912.47 -2,703.81 2,263,305.84 229,123.77 0.00 5,487.74 7 5/8 8,431.34 20.17 336.69 5,012.00 4,779.00 4,922.39 -2,708.09 2,263,315.85 229,119.72 0.00 5,498.47 Beluga 135 8,500.00 20.17 336.69 5,076.45 4,843.45 4,944.13 -2,717.45 2,263,337.79 229,110.84 0.00 5,522.00 8,501.04 20.17 336.69 5,077.43 4,844.43 4,944.46 -2,717.60 2,263,338.12 229,110.70 0.00 5,522.35 Start 986.08 hold at 8501.04 MD 8,600.00 20.17 336.69 5,170.32 4,937.32 4,975.79 -2,731.10 2,263,369.75 229,097.90 0.00 5,556.26 8,625.71 20.17 336.69 5,194.45 4,961.45 4,983.93 -2,734.60 2,263,377.96 229,094.58 0.00 5,565.07 Blossom 1-Tyonek T-1tgY 8,700.00 20.17 336.69 5,264.19 5,031.19 5,007.45 -2,744.74 2,263,401.70 229,084.97 0.00 5,590.52 8,741.34 20.17 336.69 5,303.00 5,070.00 5,020.54 -2,750.38 2,263,414.92 229,079.63 0.00 5,604.69 Tyonek T-1 8,800.00 20.17 336.69 5,358.06 5,125.06 5,039.11 -2,758.38 2,263,433.66 229,072.04 0.00 5,624.79 8,900.00 20.17 336.69 5,451.93 5,218.93 5,070.77 -2,772.02 2,263,465.62 229,059.11 0.00 5,659.05 9,000.00 20.17 336.69 5,545.80 5,312.80 5,102.43 -2,785.66 2,263,497.57 229,046.18 0.00 5,693.31 9,100.00 20.17 336.69 5,639.67 5,406.67 5,134.09 -2,799.30 2,263,529.53 229,033.24 0.00 5,727.58 9,200.00 20.17 336.69 5,733.54 5,500.54 5,165.75 -2,812.95 2,263,561.48 229,020.31 0.00 5,761.84 9,300.00 20.17 336.69 5,827.41 5,594.41 5,197.41 -2,826.59 2,263,593.44 229,007.38 0.00 5,796.10 9,400.00 20.17 336.69 5,921.28 5,688.28 5,229.07 -2,840.23 2,263,625.39 228,994.45 0.00 5,830.37 9,487.12 20.17 336.69 6,003.06 5,770.06 5,256.65 -2,852.11 2,263,653.23 228,983.18 0.00 5,860.22 Start 400.00 hold at 9487.12 MD 9,500.00 20.17 336.69 6,015.15 5,782.15 5,260.73 -2,853.87 2,263,657.35 228,981.52 0.00 5,864.63 9,553.10 20.17 336.69 6,065.00 5,832.00 5,277.54 -2,861.12 2,263,674.32 228,974.65 0.00 5,882.82 T-8 9,600.00 20.17 336.69 6,109.02 5,876.02 5,292.39 -2,867.51 2,263,689.31 228,968.59 0.00 5,898.89 9,700.00 20.17 336.69 6,202.89 5,969.89 5,324.05 -2,881.16 2,263,721.26 228,955.65 0.00 5,933.15 9,794.93 20.17 336.69 6,292.00 6,059.00 5,354.10 -2,894.11 2,263,751.60 228,943.38 0.00 5,965.68 T-10 1/8/2015 12:27:11PM Page 5 COMPASS 5000.1 Build 70 • • Halliburton Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Blossom#1 Company: Hilcorp Energy Company TVD Reference: Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Project: Ninilchik Unit MD Reference: Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Site: Blossom North Reference: True Well: Blossom#1 Survey Calculation Method: Minimum Curvature Wellbore: Blossom#1 Design: Blossom#1 wp3.b Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVOss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (^) (0) (usft) usft (usft) (usft) (usft) (usft) 6,069.00 9,805.58 20.17 336.69 6,302.00 6,069.00 5,357.48 -2,895.56 2,263,755.00 228,942.00 0.00 5,969.33 Blossom 1-BHL tgt 9,887.12 20.17 336.69 6,378.54 6,145.54 5,383.29 -2,906.68 2,263,781.06 228,931.46 0.00 5,997.27 TD at 9887.12 9,900.00 20.17 336.69 6,390.63 6,157.63 5,387.37 -2,908.44 2,263,785.17 228,929.79 0.00 6,001.68 10,000.00 20.17 336.69 6,484.50 6,251.50 5,419.03 -2,922.08 2,263,817.13 228,916.86 0.00 6,035,94 10,100.00 20.17 336.69 6,578.37 6,345.37 5,450.69 -2,935.72 2,263,849.08 228,903.93 0.00 6,070.21 10,200.00 20.17 336.69 6,672.24 6,439.24 5,482.35 -2,949.36 2,263,881.04 228,890.99 0.00 6,104.47 10,300.00 20.17 336.69 6,766.11 6,533.11 5,514.01 -2,963.01 2,263,913.00 228,878.06 0.00 6,138.73 10,400.00 20.17 336.69 6,859.98 6,626.98 5,545.67 -2,976.65 2,263,944.95 228,865.13 0.00 6,172.99 10,500.00 20.17 336.69 6,953.85 6,720.85 5,577.33 -2,990.29 2,263,976.91 228,852.20 0.00 6,207.26 10,600.00 20.17 336.69 7,047.72 6,814.72 5,608.99 -3,003.93 2,264,008.86 228,839.27 0.00 6,241.52 10,700.00 20.17 336.69 7,141.59 6,908.59 5,640.65 -3,017.57 2,264,040.82 228,826.34 0.00 6,275.78 10,800.00 20.17 336.69 7,235.46 7,002.46 5,672.31 -3,031.21 2,264,072.77 228,813.40 0.00 6,310.05 10,900.00 20.17 336.69 7,329.33 7,096,33 5,703.97 -3,044.86 2,264,104.73 228,800.47 0.00 6,344.31 11,000.00 20.17 336.69 7,423.20 7,190.20 5,735.63 -3,058.50 2,264,136.68 228,787.54 0.00 6,378.57 11,100.00 20.17 336.69 7,517.07 7,284.07 5,767.29 -3,072.14 2,264,168.64 228,774.61 0.00 6,412.83 11,200.00 20.17 336.69 7,610.94 7,377.94 5,798.95 -3,085.78 2,264,200.60 228,761.68 0.00 6,447.10 11,300.00 20.17 336.69 7,704.81 7,471.81 5,830.61 -3,099.42 2,264,232.55 228,748.74 0.00 6,481.36 11,311.92 20.17 336.69 7,716.00 7,483.00 5,834.38 -3,101.05 2,264,236.36 228,747.20 0.00 6,485.45 T-50 11,400.00 20.17 336.69 7,798.68 7,565.68 5,862.27 -3,113.07 2,264,264.51 228,735.81 0.00 6,515.62 11,464.26 20.17 336.69 7,859.00 7,626.00 5,882.61 -3,121.83 2,264,285.04 228,727.50 0.00 6,537.64 T-60 11,500.00 20.17 336.69 7,892.55 7,659.55 5,893.93 -3,126.71 2,264,296.46 228,722.88 0.00 6,549.89 11,600.00 20.17 336.69 7,986.42 7,753.42 5,925.59 -3,140.35 2,264,328.42 228,709.95 0.00 6,584.15 11,700.00 20.17 336.69 8,080.29 7,847.29 5,957.25 -3,153.99 2,264,360.37 228,697.02 0.00 6,618.41 11,800.00 20.17 336.69 8,174.16 7,941.16 5,988.91 -3,167.63 2,264,392.33 228,684.08 0.00 6,652.68 11,900.00 20.17 336.69 8,268.03 8,035.03 6,020.56 -3,181.27 2,264,424.29 228,671.15 0.00 6,686.94 11,915.95 20.17 336.69 8,283.00 8,050.00 6,025.61 -3,183.45 2,264,429.38 228,669.09 0.00 6,692.40 1/8/2015 12:27:11PM Page 6 COMPASS 5000.1 Build 70 • • Halliburton HALLI ,. U RTO Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Well Blossom#1 Company: Hilcorp Energy Company #1 @ 233.00usft(Saxon 169(215'GL+ Project: Ninilchik Unit ° .t ( k Plan:Blossom#1 @ 233.00usft(Saxon 169(215'GL+ Site: Blossom True Well: Blossom#1 Minimum Curvature Wellbore: Blossom#1 lliolgoblarl. 4' Design: Blossom#1 wp3.b Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting •Shape (°) (°) ; (usft) (usft) (usft) (usft) (usft) Blossom 1-Tyonek T-1 tgt 0.00 0.00 5,217.00 4,908.50 -2,754.51 2,263,303.00 229,073.00 -plan misses target center by 81.20usft at 8625.71usft MD(5194.45 TVD,4983.93 N,-2734.60 E) -Circle(radius 100.00) Blossom 1-BHL tgt 0.00 0.00 6,302.00 5,357.48 -2,895.56 2,263,755.00 228,942.00 -plan hits target center -Circle(radius 100.00) Blossom 1 -Beluga T-1 tgt wp3b 0.00 0.00 2,233.00 4,224.17 -2,537.18 2,262,614.00 229,275.00 -plan misses target center by 450.80usft at 5742.23usft MD(2536.55 TVD,3990.13 N,-2299.88 E) -Circle(radius 100.00) Blossom 1-Beluga T-1 tgt 0.00 0.00 2,233.00 3,521.33 -2,073.38 2,261,901.00 229,723.00 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") 4,202.06 2,000.00 10 3/4" 10-3/4 12-1/4 8,400.00 4,982.58 7 5/8" 7-5/8 8-1/2 11,915.95 8,283.00 5"Liner 5 6-1/8 De ., = wip • = t s 9,553.10 6,065.00 T-8 9,794.93 6,292.00 T-10 8,741.34 5,303.00 Tyonek T-1 11,311.92 7,716.00 1-50 11,464.26 7,859.00 T-60 8,431.34 5,012.00 Beluga 135 Plan'Annotations easured Vertical Local Coordinates ®'= Depth +N/-S +E/-W' (usft) (usft) (usft) Comment 250.00 250.00 0.00 0.00 Start Build 3.00 370.00 369.92 3.32 -1.92 Start DLS 5.00 TFO-0.26 1,693.08 1,367.84 653.01 -384.76 Start 3361.70 hold at 1693.08 MD 5,054.79 2,213.22 3,455.18 -2,037.99 Start DLS 5.00 TFO 177.20 5,904.15 2,659.62 4,085.22 -2,344.43 Start 2400.00 hold at 5904.15 MD 8,304.15 4,892.61 4,882.13 -2,690.74 Start DLS 3.00 TFO 140.33 8,501.04 5,077.43 4,944.46 -2,717.60 Start 986.08 hold at 8501.04 MD 9,487.12 6,003.06 5,256.65 -2,852.11 Start 400.00 hold at 9487.12 MD 9,887.12 6,378 54 5,383.29 -2,906.68 TD at 9887.12 1/8/2015 12:27:11PM Page 7 COMPASS 5000.1 Build 70 0 • 0 _c f / o w 0 , § ▪ c # -0 a) / k \ -c •x — c u � o 0 = 2 c k 01 ® a) co (-) EC:-.) \ 3 U f $ oma o. § )// o _ 2 ° Ln R o 3 E up 4-1 \ / � C. 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(n m 2 Z Z d0 11 O Q • • Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Tuesday, March 17, 2015 4:37 PM To: Davies, Stephen F (DOA); Monty Myers; David Buthman Cc: Schwartz, Guy L(DOA) Subject: RE: Blossom 1 (PTD#215-015) - Fresh Water Aquifers Steve, Our plan forward would be to provide surface casing depth justification that you requested below. We'll get some more information about which well our calculations came from as soon as Dave Buthman returns to work next week, as the information came from him and the rest of us have been unable to duplicate. We'll have him show us how this is done so we don't run into a similar situation again. Regarding the mud logs and additional logs you may require, Hilcorp will comply with whatever is written on the conditions of approval. Mud logging was already part of the Drilling Procedure from base of conductor to TD (Page 8). Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, March 17, 2015 4:00 PM To: Monty Myers Cc: Schwartz, Guy L (DOA); Luke Keller Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Aquifers Monty, So that I'm completely clear on Hilcorp's path forward: • Will Hilcorp be providing the surface casing depth justification that I requested below? Or • Will Hilcorp be providing a revised plan of drilling operations for Blossom 1 that: o includes clear steps to ensure all freshwater aquifers—as indicated by the Blossom 1 well logs—will be isolated with cement, and o that cement isolation of all freshwater aquifers will be demonstrated by running appropriate cement evaluation logs? Also, will Hilcorp please let me know which well yielded the information provided on page 7 of the Blossom 1 Permit to Drill application? Again, I'd like to confirm Hilcorp's calculations and then examine the TDS content of formation fluids in the sands beneath 1040' in that same well. Thanks again for your help, Steve Davies 1 • S From: Luke Keller To: Davies,Stephen F(DOA1 Cc: Monty Myers Subject: Drinking Water Wells Near Blossom Pad Date: Wednesday,March 18,2015 8:16:38 AM Attachments: WELTS Water Well Search Blossom 031715.xlsx Steve, Attached is a list of wells we found of the ADNR website that are in close proximity to the Blossom #1 surface location. Looks like the deepest is the one on the GO pad which is 230'. Luke From: Tara Vicente- (C) Sent: Tuesday, March 17, 2015 5:22 PM To: Luke Keller Cc: Gretchen Stoddard; David Duffy Subject: Blossom - drinking water wells I don't think this is the information you need for AOGCC. ADNR WELTS database has drilling logs, but a quick search around Blossom pad turned up only drinking water wells that are less than 200' deep. Not sure if we could find deeper wells or any salinity data in the area without looking more into it. I saved this excel file plus the well logs in 0:\Alaska\Depts\EHS\Environmental\PROGRAM\Permitting\Ninilchik Unit\Blossom\Water Well Information Thanks! Tara Vicente Environmental Support Contractor Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 100 Anchorage,AK 99503 Cell: 907.351.4690 tvicentefhilcorp.com • 0 0 V M .7 0 O N U) co LLl M O m 011-1 0 N 01 N ,"I t V 0- 0) G m C .-q O >- }¢ 0 LL G r w Q = O9 F- ..t 0 LY K 0 Oy OJ Ln E vL Q ' x O 0 •` .-L N 0 0 x x O , LQ I- J J z oO x O z o.. x a. < a Ce m VNi J N z a N R 0 = Y N N g N OY Y a ,I L• ~itfmz m v~iE0f 3 1 Z 1- O O• 7 I -i w Q• O z LL z 0 a i Z 0 ~ 0 x = F=- amQm C K 00 0 O oO Q Q H = = r Q O 1 x m a o m f 3 i 3 I—I— dI— K N N .-L CO 0 N N d' C CO 00 0 CO 0 m W CO O > C 00 IN 9 O C N W ,-.1O Z n Q m N M c L v r, of In E N N .-1 N 0 L) 0 0 w m I O 1 : L z z Z C O 0 6 Z Q c1 W .:'.1 Oz O O - (, J J J -' w - ce (n W w (62 0 W Z 0 0_ Z 0 = x 0 m o m J Lu J J aJ T. 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Or • Will Hilcorp be providing a revised plan of drilling operations for Blossom 1 that: o includes clear steps to ensure all freshwater aquifers—as indicated by the Blossom 1 well logs—will be isolated with cement, and o that cement isolation of all freshwater aquifers will be demonstrated by running appropriate cement evaluation logs? Also, will Hilcorp please let me know which well yielded the information provided on page 7 of the Blossom 1 Permit to Drill application? Again, I'd like to confirm Hilcorp's calculations and then examine the TDS content of formation fluids in the sands beneath 1040' in that same well. Thanks again for your help, 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.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Tuesday, March 17, 2015 3:44 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA); Luke Keller Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Aquifers No problem at all Steve to mudlog and LWD with GR/RES and NEU/DENS for the well for all intervals. If you want to write that in to the conditions of approval. To me, we will ensure that all zones are protected by having every zone isolated by cement.And if we need to run a CBL for verification that should be reasonable. I will get you the directions to where the water wells are located, as well as the one we just drilled. Thank you! Monty M Myers Drilling Engineer 1 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, March 17, 2015 3:25 PM To: 'Monty Myers' Cc: Schwartz, Guy L(DOA) Subject: Blossom 1 (PTD#215-015) - Fresh Water Aquifers Thanks Monty, but one of AOGCC's main responsibilities is to ensure protection of freshwater aquifers. What I'm seeking is justification from Hilcorp that setting surface casing at 2500' MD in Blossom 1 will indeed protect freshwater (see Regulation 20 AAC 25.030(a)(6)). Note that Regulation 20 AAC 25.990(27) states: (27) 'freshwater"means water that(A) has a total dissolved solids concentration of less than 10,000 mg/l, and occurs in a stratum not exempted under 20 AAC 25.440; or (B) occurs in a stratum that serves as a source of drinking water for human consumption; The information Hilcorp provided on page 7 of the Blossom 1 Permit to Drill application was quite specific: All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 at the 171 — 194' sand, 1800 at the 505 —535' sand. and 6000 ppm at the 1040" sand. Furthermore, the TGAS (total gas) curve from offset mud logs beEns registering shallow gas at depths just below the sandstone bed at 200'. Could Hilcorp please tell me which well yielded these results? I'd like to confirm them and then examine the TDS content of formation fluids in the sands beneath 1040' in that same well. To complete the Permit to Drill application for Blossom 1 so that I can pass it along in AOGCC's review process, please provide justification as to why setting surface casing at 2500' MD (about 1575'TVD)will protect freshwater aquifers at Blossom 1. As I explained to Luke in my email of March 3, 2015 (attached below), since Blossom 1 will be the first well from a new drill site, it is AOGCC's policy to require a mud log and at least a minimum well log suite consisting of gamma ray, resistivity, and porosity logs from base of conductor pipe to TD of the well. The shallow portions of these well logs will confirm the depth to base of freshwater aquifers in the vicinity of the Blossom 1 drill site. Thank you for the water well records. How many feet, and in which directions are these two water wells from Blossom 1? Thanks for your help, 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.davies@alaska.gov. From: Davies, Stephen F (DOA) [mailto:steve.davies@@alaska.gov] Sent: Tuesday, March 03, 2015 11:26 AM To: Luke Keller 1 Cc: Schwartz, Guy L (DOA) • Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Zones Hi Luke, I'd like to keep the Blossom 1 Permit to Drill application moving through AOGCC's review process. I never did receive a response on the questions that I sent on January 21st, below. Since Blossom 1 will be the first well from a new drill site, it is AOGCC's policy to require a mud log and at least a minimum well log suite consisting of gamma ray, resistivity, and porosity logs from base of conductor pipe to TD of the well. 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.davies@alaska.gov. From: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Tuesday, March 17, 2015 1:46 PM To: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: Blossom 1 (PTD #215-015) - Fresh Water Zones Steve, I was hoping to get some closure with the Blossom 1 PTD so we could add this to our list of projects that are ready to go. I am looking to answer the email you had for Luke below... The attached spreadsheet is the way the salinity calculations were done for the Falls Creek Area. I attached the 2 nearest water wells.The deepest is 120'. We are planning to set conductor to about that depth. Let me know what other questions you have. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Gretchen Stoddard Sent: Friday, March 06, 2015 5:08 PM To: Luke Keller; Monty Myers Cc: Jessica Morehouse; Julieanna Orczewska - (C) Subject: FW: Blossom 1 (PTD #215-015) - Fresh Water Zones 2 • • This is the data behind this issue. Not sure it directly answers our AOGCC question, but this is what is behind what we wrote. Thanks Gretchen From: David Buthman Sent: Friday, March 06, 2015 4:01 PM To: Gretchen Stoddard Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Zones Hi Gretchen, Attached are the calculations. Rgds, Dave From: Gretchen Stoddard Sent: Friday, March 06, 2015 9:49 AM To: David Buthman Subject: Fwd: Blossom 1 (PTD #215-015) - Fresh Water Zones Can u help me answer please? Sent from my GCI smartphone. Original message From: Luke Keller Date:03/06/2015 9:43 AM (GMT-09:00) To: David Duffy , Jessica Morehouse , Monty Myers , "Julieanna Orczewska- (C)" , Kelley Nixon , Gretchen Stoddard Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Zones We got that from Dave Buthman on another well down on the bluff. From: David Duffy Sent: Friday, March 06, 2015 8:40 AM To: Jessica Morehouse; Monty Myers; Julieanna Orczewska - (C); Kelley Nixon; Gretchen Stoddard Cc: Luke Keller Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Zones Where did we get the data referenced at pg. 7 of the PTD? All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand. 1800 ppm at the 505 —535' sand, and 6000 ppm at the 1040` sand Furthermore, the TGA (total gas) curve from offset mud logs begins registering shallow gas at depths just below the sandstone bed at 200' My guess would be either Buthman or whoever drilled our water well.... But it seems odd to have water well data down to 1040'. 3 0_. _„ , _._ .. �. ® From: Jessica Morehouse Sent: Friday, March 06, 2015 7:58 AM To: Monty Myers; Julieanna Orczewska - (C); Kelley Nixon; David Duffy; Gretchen Stoddard Cc: Luke Keller Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Zones Hmmmm... One place we can try looking is on DNR's Alaska Mapper, which displays where water rights are held within the state, which could indicate where some wells are located in the near area, however maybe not all of them. http://dnr.alaska.gov/MapAK/ We could also do a DNR Case File search to find if there are TWUA's and/or water rights that aren't displayed on the mapping tool here: http://dnr.alaska.Rov/projects/las/ Both of these tools would only inform us of wells in the area. I do not know where we could track down salinity results unless some sampling was previously done. Kelley, David, and Gretchen—Any other potential thoughts on below? I am in ICS 300 training all day today, but I will check in on my breaks to see what I can find out. Jess From: Monty Myers Sent: Friday, March 06, 2015 7:09 AM To: Jessica Morehouse; Julieanna Orczewska - (C) Cc: Luke Keller Subject: Blossom 1 (PTD #215-015) - Fresh Water Zones Good morning Jessica! We are trying to finalize some questions the AOGCC has on neighboring water wells around the Blossom Pad. Can you help me answer Steve's questions below or point me in the right direction to find the info? Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) Sent: Wednesday, January 21, 2015 6:12 PM To: Ikeller@ hilcorp.com Subject: Blossom 1 (PTD #215-015) - Fresh Water Zones Luke, Page 7 of the Permit to Drill application for Blossom 1 indicates that all known potential fresh water zones exist above 200' according to Hilcorp's salinity calculations for neighboring water wells. Could you tell me which wells were used? Could Hilcorp please provide the salinity calculations from those wells? What is the deepest water well in the vicinity of the Blossom 1 surface location? Thanks, Steve Davies 4 • • Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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.davies@alaska.gov. 5 • Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Thursday, February 05, 2015 10:11 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: Blossom 1 (PTD #215-015) - Fresh Water Zones I'll get with them ASAP. I apologize for the delay. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, February 05, 2015 9:45 AM To: Luke Keller Cc: Schwartz, Guy L (DOA) Subject: FW: Blossom 1 (PTD #215-015) - Fresh Water Zones Luke, I never received a reply to my inquiry, below. Could you please forward my request to the geoscience team? Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Wednesday, January 21, 2015 6:12 PM To: Ikeller( hilcorp.com Subject: Blossom 1 (PTD #215-015) - Fresh Water Zones Luke, Page 7 of the Permit to Drill application for Blossom 1 indicates that all known potential fresh water zones exist above 200' according to Hilcorp's salinity calculations for neighboring water wells. Could you tell me which wells were used? Could Hilcorp please provide the salinity calculations from those wells? What is the deepest water well in the vicinity of the Blossom 1 surface location? Thanks, Steve Davies Senior Petroleum Geologist 1 Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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.davies@alaska.gov. 2 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, February 05, 2015 9:45 AM To: Ikeller@hilcorp.com Cc: Schwartz, Guy L (DOA) Subject: FW: Blossom 1 (PTD#215-015) - Fresh Water Zones Luke, I never received a reply to my inquiry, below. Could you please forward my request to the geoscience team? Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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.davies@alaska.gov. From: Davies, Stephen F (DOA) Sent: Wednesday, January 21, 2015 6:12 PM To: Ikeller@hilcorp.com Subject: Blossom 1 (PTD #215-015) - Fresh Water Zones Luke, Page 7 of the Permit to Drill application for Blossom 1 indicates that all known potential fresh water zones exist above 200' according to Hilcorp's salinity calculations for neighboring water wells. Could you tell me which wells were used? Could Hilcorp please provide the salinity calculations from those wells? What is the deepest water well in the vicinity of the Blossom 1 surface location? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 Anchorage,AK 99501 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 1 • • Davies, Stephen F (DOA) From: David Duffy <dduffy@hilcorp.com> Sent: Thursday, January 22, 2015 12:00 PM To: Davies, Stephen F (DOA) Subject: RE: Blossom 1 (PTD#215-015) - Surface Location Tract Status Steve, We referrer to the Blossom Pad site as Tract 306. The surface estate is owned by the Blossom Family. The subsurface estate is owned by the McLaughlin family. Hilcorp has a written agreement with the surface owners for the pad. We also have leased the oil and gas rights from the landowner(subsurface). Should you require any additional information about the site of the Blossom 1 surface location, please give me a call. David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffy@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s)only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, January 21, 2015 5:30 PM To: David Duffy Subject: Blossom 1 (PTD #215-015) - Surface Location Tract Status David, Who is (are) the owners and landowners of the onshore portion of Section 14,T1N, R13W, SM,the site of the Blossom 1 surface location? Does Hilcorp have a lease commitment with them? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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.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: 624--)... C91_,(__. 7 PTD: 2 / U (c- -Development Service _Exploratory _Stratigraphic Test Non-Conventional � � i FIELD: / L 1 e.— POOL: I►,i L� ;Ck. — 4 �'a'l�Q 'ee _S 41, 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 welllogs are also required.5itc •-i-/t-is t s —1 f i v,..;71 C-z;e/(' f r ,41. &t. 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E co 6 a) a) a) 'a= a>), a) `0 E o c � 3, c, , i- H I-; •y', •, o' > = a a ' o; a 0, @ E. 0 c m t�- 0 0. c, a v a a a) 0 m, o o. 2', 2' �, m v. -o. 'v = O O t, 0 �; o, 0 m 0, 0. o, ❑ • �' � z' a -) � �, �' �' �n, °=; oo; a; a; U �' da; U; CnUU, Uv' Q �� Q �� o' m� m� v, �, 2' M' a, ❑, � � v .._._ N en O' � O) O�- �- .- V �- O (N NN NM V N N (NN aN N OM M M c.M U) t0 O Mn M MD s N o +,_ N a) N O O _ O C ja N �,/� co N al ' w ❑ to t� 0) 0 c� ❑ N y /��L/1 lO E (N Int C N °.E �k C N A�,� N N 0 0) (D 0 E ', '', .0 L c .. _0 .. ❑ E Q �' O Oa. .J O a O f a Q a u) ♦ w a (9 c7 Q u) • Well History File APFENDX Infos n ration 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. Technical Report Title Date Client: Hilcorp Alaska, LLC Field: Ninilchik Unit Rig: Saxon 169 Date: July 14, 2015 Surface Data Logging End of Well Report Blossom 1 Blossom 1 PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Hilcorp Alaska, LLC Rig: Saxon 169 Well: Blossom 1 & Blossom 1 PB1 Field: Ninilchik Unit Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-133-20648-00-00 (Blossom 1) 50-133-20648-70-00 (Blossom 1 PB1) Sperry Job Number: AK-AM-0902378615 Job Start Date: 23 May 2015 Spud Date: 23 May 2015 Total Depth: 11200’ MD, 7585’ TVD (Blossom 1) 12098’ MD, 8407’ TVD (Blossom 1 PB1) North Reference: True Declination: 16.460° Dip Angle: 73.183° Total Field Strength: 55197 nT Date Of Magnetic Data: 05 May 2015 Wellhead Coordinates N: North 60° 10’ 24.684” Wellhead Coordinates W: West 151° 28’ 24.181“ Drill Floor Elevation 233.20’ Ground Elevation: 215.20’ Permanent Datum: Mean Sea Level SDL Engineers: Jeremy Tiegs, Eric Andrews, Jacob Robertson SDL Sample Catchers: Mario Luescher, Hilarion Castro, Nate Conway, Brad Daniel Company Geologist: David Buthman Company Representatives: R. Pederson, D. Yessak, S. Hauck, L. Toussant SSDS Unit Number: 117 DAILY SUMMARY 05/22/2015 SDL continues on location from previous well. Spot and set MWD and mudlogging shacks. 05/23/2015 Arrived on site and began rigging up unit. Continued rigging up and began mixing spud mud. Completed function, time annular, and knife valve tests with state representative and then began picking up drill pipe and racking back. Finished mixing spud mud and function test solids control equipment. Finished picking up drill pipe and prepping to pick up Bottom hole assembly at time of report. 05/24/2015 Finished picking up drill pipe and heavy weight drill pipe. Made up Bottom Hole Assembly and tagged at 110' MD. Circulated conductor with fresh water then displaced mud to 8.8 pounds per gallon Spud-Mud. Spud from 110' MD to 237' MD. Circulated bottoms up and pulled back out of hole to make up the remainder of the bottom hole assembly. Finished making up bottom hole assembly and ran in hole to bottom. Commenced directional drilling the 13.5" surface interval to 1214' MD at time of midnight report Max Gas: 13 Units Fluids: 0 Fluids lost. 05/25/2015 Drilled ahead to 1,226' MD, pumped 25 barrels of fresh water at 25 barrels weighted to 10.0 pounds per gallon tandem sweeps; 10% increase in cuttings. Ran a wiper trip to jars with no complications. No fill, once back on bottom. Continued drilling to 1,971' MD, pumped 25 barrels of fresh water at 25 barrels weighted tandem sweeps; no increase in cuttings. Once again, continued drilling ahead to 2,464' MD at time of midnight report. MaxGas: 139 Units Fluids: 0 Fluids lost. 05/26/2015 Continued drilling ahead from 2464’ MD to surface TD of 2506’ MD and circulated hole clean. Tripped out of hole from 1200’ MD to 770’ MD and lost returns. Established full returns after some troubleshooting and pulled out of hole to 175’ MD. Serviced top drive, draw works, crown, and cleaned mud pump screens. Ran back in hole washing and reaming from 175’ MD to 2506’ MD. Pumped high viscosity marker sweep and circulated hole clean. Tripped out of hole from 2506’ MD, rigged down bottom hole assembly, and rigged up for casing run. Made up float equipment and tested floats. Started running in hole with 10 ¾” Casing. Max Gas: 66 Units Fluids: 262 bbl Fluid lost downhole. 05/27/2015 Finish rigging up to run casing, tested float equipment, and began running in hole with 10 3/4" casing to 2,495' MD; lost 12 barrels to well during trip. Once on bottom we rigged up cement head and circulated/conditioned mud before pumping cement job. Nippling down diverter at time of midnight report. Max Gas: 40 Units Fluids: 95 bbl Fluid lost downhole. 05/28/2015 Began nippling up Blowout Preventer, hauled spud mud off to G&I, cleaned pits, and started building a 300 barrel batch of new mud. Finished nippling up Blowout Preventer and completed shell test before conducting Blowout Prevention Test. Preparing to pick up drill pipe at time of midnight report. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. 05/29/2015 Finished testing BOP's and performed casing test to 2,700 psi; everything went well. Ran in hole while picking up 4.5” drill pipe down to 2390’; tagged cement and began circulating bottoms up. Circulated at idle, over-boarding thick spud mud and watering back. Once mud diluted back enough to stay on shakers we increased rate to 190 gallons per minute. Circulated hole clean and then slip and cut drill line. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. 05/30/2015 Finished slipping and cutting the drill line, pulled out of the hole to surface, picked up directional tools, shallow tested MWD tools, ran in hole to 2322’ MD, lined up pumps, and started drilling out float equipment and shoe at 2,491' MD, displaced well over to 9.2 pounds per gallon: 6% KCL/PHPA mud, performed F.I.T. test at 12.0 EMW , and drilled ahead into intermediate section until midnight depth of 2775’ MD. Max Gas: 12 Units Fluids: 0 bbl Fluid lost downhole. Geology: 80% Sand, 10% Siltstone, 5% Claystone, 5% Sandstone. 05/31/2015 Ran a wiper trip back to the shoe and picked up 12 joints of heavy weight drill pipe. Ran back into the hole after the wiper trip and continued drilling ahead to 3,377' MD. Pumped a Hi-Vis sweep (230 vis) with no increase in cuttings at shakers. Drilled ahead to 3,583' MD and short tripped back to shoe; tight spots at 3,522' MD, 3,026' MD, and 2952' MD that we were able to work through on the elevators. Ran back in hole to 2719' MD, pumped HI-Vis WALL-NUT sweep; 40% increase in cuttings at shakers. Circulated hole clean and continued to run into hole to 3587' MD, drilled ahead to 3,745' MD, pumped Hi-Vis with WALL-NUT & CON-DET sweep; cuttings increased 60% at shakers. Max Gas: 83 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Sand, 30% Claystone, 20% Siltstone 06/1/2015 Drilled ahead to 4,513' MD, pumped a high viscosity and a low viscosity sweep; 15% increase in cuttings at the shakers. Started a short trip back to the shoe on elevators and serviced rig. Ran in hole to bottom with no issues or fill. Continued drilling ahead to 4,886' MD, pumped another high viscosity sweep with walnut; 60% increase in cuttings at shakers. Wiper tripped up to 4,504' MD, circulated bottoms up, and ran back into the hole with no issues. Max Gas: 431 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Siltstone, 30% Sand, 10% Claystone, 10% Tuff 06/2/2015 Drilled to 5,259' MD and pumped a low viscosity, low weight sweep; followed by a high viscosity, high weight sweep; 30% increase in cuttings at shakers. Short tripped to 4,138' MD running into a couple of tight spots. Pumped a high viscosity sweep and had a 15% increase of cuttings at the shakers. Serviced the rig and ran into the hole to drill ahead; drilling at 5,678' at time of midnight report. Max Gas: 297 Units Fluids: 0 bbl Fluid lost downhole. Geology: 60% Sand, 20% Siltstone, 10% Claystone, 10% Coal 06/3/2015 Continued drilling ahead to 5,740' MD, pumped a high viscosity sweep and observed a 25% increase in cuttings. Drilled to 5,999' MD, pumped another high viscosity sweep and had a 25% increase in cuttings. Then we pumped low viscosity sweep with low weight followed by a high viscosity sweep with high weight and had a 60% increase in cuttings. Circulated hole clean and short tripped out of hole to 4,888' MD encountering multiple tight spots. Serviced the rig and pumped another high viscosity sweep with an increase of 15% at bottoms up and a 50% increase at surface to surface. Ran in hole to bottom and drilled ahead to 6095' MD, worked pipe and continued drilling ahead to 6127', pumped a high viscosity sweep and observed a minimal increase in cuttings. Max Gas: 227 Units Fluids: 0 bbl Fluid lost downhole. Geology: 70% Sand, 20% Siltstone, 10% Coal 06/4/2015 Drilled to 6,433' MD, pumped a high viscosity sweep, and had a 20% increase in cuttings at shakers. Short tripped to 5,999' MD with no over pull, and pumped tandem sweeps; low viscosity, low weight followed by a high viscosity, high weight with a 50% increase in cuttings at the shakers. Serviced rig, ran in hole to bottom, and continued drilling ahead to 6,633' MD. Pumped a high viscosity sweep while drilling ahead and had a 40% increase in cuttings at the shakers. Drilled to 6,795' MD where the hole section was called as total depth. Pumped a high viscosity sweep showing 10% returns at the shakers. Took out of hole to 5,649' MD and pumped a 50 barrel tandem sweep; 25 barrels of a Low viscosity, low weight sweep, chased by 25 barrels of a high viscosity, high weight sweep; showing a 100% increase in cuttings followed by a 200% increase (hole unloaded) in cuttings when the high viscosity, high weight sweep came back. Taking out of hole to 4000’ MD where we will pump another tandem sweep. Max Gas: 123 Units Fluids: 0 bbl Fluid lost downhole. Geology: 40% Sand, 40% Siltstone, 20% Claystone 06/05/2015 Took out of hole on elevators to 4200' MD and pumped another 50 barrel tandem sweep. Circulated the hole clean and began taking out on elevators to 3,022' MD, back reaming to 3,010' MD. Once inside of the casing we circulated a bottoms up and observed a 10% increase in cuttings. Continued taking out of hole to bottom hole assembly, pulled sources, downloaded/uploaded MW D tool, and installed sources. Started running in hole to bottom for Mad Pass logs in open hole. Once on bottom, we observed a 50% increase in cuttings. Pumped a sweep once pumps were up and observed the sweep to have an increase in 25% of cuttings at the shakers. Max Gas: 45 Units Fluids: 38 bbl Fluid lost downhole. 06/06/2015 Continued to Mad pass to 6002' MD and pumped a high viscosity sweep; observing a 10% increase in cuttings at the shakers. Continued Mad passing to 5500' MD and pumped a tandem sweep. Continued to Mad pass up the hole to 3525' MD and pumped another high viscosity sweep. Currently at 2,900' and mad passing up the hole at time of reporting. Max Gas: Units Fluids: 0 bbl Fluid lost downhole. 06/07/2015 Continued to Mad pass to 2612' MD and pumped a tandem sweep. Pulled up into the casing and flow checked the well; no increase or decrease. Pulled out of hole to bottom hole assembly, removed sources, downloaded MWD tool, finished laying down bottom hole assembly, checked flow, cleaned stack, changed rams, and tested for casing run. Rigged up Weatherford casing equipment and held a pre job safety meeting before starting to run 7 5/8 casing. Ran in hole to 2474’ MD and circulated a surface to surface to circulate out bubble then continued running on hole at time of morning report. Max Gas: 9 Units Fluids: 0 bbl Fluid lost downhole. 06/08/2015 Finished running the 7 5/8" casing down hole with no issues, and pumped a surface to surface circulation. Rigged down the Volant tool, rigged up cement head, and continued to circulate. Pumped Cement, and then rigged down cement head. Installed well head pack off, changed out rams on blow out preventer and began pressure testing blow out preventer at time of reporting. Max Gas: 9 Units Fluids: 8 bbl Fluid lost downhole. 06/09/2015 Successfully pressure tested the blow out preventer. Picked up enough singles to reach total depth and racked them back. Picked up BHA, MWD tools, mud motor, and began running in hole. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. 06/10/2015 Finished running into the hole and made up cuttings bed impellers every other stand. Ran in hole to 6480' MD and circulated surface to surface while rigging up for casing test; test passed. Continued running in hole to 6631' MD and displaced the well to 9.1 pounds per gallon mud while drilling out cement. Drilled to 6815' MD, circulated bottoms up, and conducted a F.I.T. test to 12.0 pounds per gallon mud weight equivalent; passed. Continue to drill ahead at time of midnight reporting. Max Gas: 61 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Siltstone, 40% Claystone, 10% Sand 06/11/2015 Drilled ahead to 4,178’ MD and pumped a high viscosity sweep. Continued drilling to 7,468’ MD and pumped a tandem low viscosity/high viscosity sweep. Continued drilling ahead to 7,818’ MD and pumped another tandem sweep. Circulated the hole clean and began pulling out of hole for a wiper trip. Max Gas: 224 Units Fluids: 0 bbl Fluid lost downhole. Geology: 60% Claystone, 20% Sand, 20% Siltstone 06/12/2015 Wiper tripped to 6,730' MD, serviced the rig, and ran back into the hole to continue drilling ahead. Drilled to 8,315' MD and pumped a high viscosity sweep. Continued drilling ahead to 8,809’ MD and pumped a tandem sweep; observed a 10% increase in cuttings. Circulated the hole clean and began wiper tripping from 8809’ MD. Max Gas: 425 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Sand, 20% Sandstone, 10% Siltstone, 10% Claystone, 10% Tuff 06/13/2015 Wiper tripped to 7,753’ MD and ran back to bottom. Drilled to 9,305' MD and pumped a high viscosity sweep. Continued drilling ahead to 9,801' MD and pumped a tandem sweep. Started wiper tripping to the shoe and pulled out of hole to 8.828' MD. Pulled to 7,500' MD on elevators and pumped out of the hole to 7,400' MD. Max Gas: 786 Units Fluids: 0 bbl Fluid lost downhole. Geology: 40% Sandstone, 40% Sand, 20% Siltstone 06/14/2015 Finished pulling out to shoe and flow checked the well; no flow/losses. Ran back into the hole to 9,690' MD and then washed and reamed down to 9,801' MD. Continued drilling ahead 10,025' MD and experienced high torque. Pumped a high viscosity sweep and drilled ahead to 10,202' MD to pump another high viscosity sweep; observed a 50% increase in cuttings. Continue to drill ahead at 10,420' MD at time of reporting. Max Gas: 1808 Units Note: We encountered the 1808 Units from bottoms up, after running in hole from the 9801' MD Wiper Trip. Fluids: 0 bbl Fluid lost downhole. Geology: 40% Sandstone, 30% Sand, 20% Coal, 10% Siltstone 06/15/2015 Drilled ahead to 10,854' MD and pumped a tandem sweep, followed by a high viscosity sweep. Circulated the hole clean, pulled 1 stand and flow-checked the well; everything went well. Pulled out of hole to 9,734' MD with no issues, and then ran back in hole picking up 10 singles. Reached bottom and washed down the last stand. After the trip, the hole unloaded mostly fine coal after circulating bottoms up. Continue drilling ahead at 11,047’ MD. Max Gas: 1341 Units Fluids: 0 bbl Fluid lost downhole. Geology: 60% Siltstone, 20% Sand, 20% Sandstone 06/16/2015 Drilled ahead to 11,300' MD and pumped a high viscosity sweep; observed a 20% increase in cuttings. Continued drilling ahead to 11,850' MD and pumped a tandem sweep; observed the sweep to come back on time with a 200% increase in cuttings. Circulated the hole clean and began to pull out of the hole for a wiper trip. Tight spots at 11,050' MD - 11,041' MD, 10,994' MD, 10,902' MD; pulled up to 10,793' MD and began picking up enough singles to reach newly proposed TD. Max Gas: 1995 Units Fluids: 0 bbl Fluid lost downhole. Geology: 40% Siltstone, 30% Coal, 20% Sand, 10% Sandstone 06/17/2015 Finished running into the hole, tagged 35' of fill and circulated a bottoms up. Circulated a surface to surface before the hole cleaned up and we were able to drill ahead. Drilled to 12,098' MD, noticed an increase in torque, tried to back ream up but became stuck. Pumped a high viscosity sweep; no increase in cuttings. Continue to free the pipe by pumping sweeps, working the pipe, and jarring at time of report. Max Gas: 775 Units Fluids: 0 bbl Fluid lost downhole. Geology: 70% Sand, 10% Siltstone 06/18/2015 Worked pipe and attempted to rotate, with no luck. Rigged up E-line and attempted to run into the hole but could only get to 2200' MD. Rigged up circulating equipment in order to pump E- line down but could not circulate. Rigged down E-line and worked pipe in hopes to establish circulation with no luck. Rigged up and ran into the hole with the E-line free point tool but could only get to 2300' MD. Rigged down E-line and rigged up a different truck with a smaller diameter line, but after multiple attempts were only able to run to 1,930' MD. Rigged down E-line and attempted once again to regain circulation while working pipe. Rig up Schlumberger’s pump truck at time of report. Max Gas: 41 Units Fluids: 2226 bbl Fluid lost downhole. 06/19/2015 Finished rigging up Schlumberger and held a pre job safety meeting. Pressure Tested lines to 7,500 psi, pressured up string to 6,900 psi, and then bled back to 5,900 psi with no returns. Rigged down Schlumberger pump truck and continued working/jarring pipe. Rigged up slick line and ran in hole with 2" dummy gun drift; no luck. Rigged down slick line, changed out long bails back to drilling bails, and Slip & cut drill line. Continuing to jar and work pipe free. Max Gas: 9 Units Fluids: 0 bbl Fluid lost downhole. 06/20/2015 Continued rig maintenance while waiting on coil tubing. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. 06/21/2015 Continued running hole with coil tubing, tested blow out preventer, and rigged up injector head. Run into the hole with coil tubing to perforate at time of report. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. Kicked off at 7500’ MD 07/01/2015 Ran into the hole to 7,499’ MD, began time drilling at 1’ per hour to 7,505’ MD, and increased to 4’ per hour at 7,523’ MD. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. Geology: 90% Siltstone, 10% Cement. 07/02/2015 Continued time drilling at 4’ per hour until we reached 7,535’ MD, and then we rotated and slid to 7,881’ MD and pumped hi and low viscosity sweeps. Pulled and ran short trip to kick off at 7,500’ MD. Ran in the hole and continued drilling ahead at 8,339’ MD. Max Gas: 0 Units Fluids: 0 bbl Fluid lost downhole. Geology: 80% Siltstone, 10% Claystone, 10% Coal 07/03/2015 Continued drilling ahead to 9,456' MD, pumped a sweep, and began short trip. We are currently pulling out of the hole into the casing shoe. Max Gas: 606 Units Fluids: 0 bbl Fluid lost downhole. Geology: 70% Sandstone, 30% Sand 07/4/2015 TOOH to casing shoe at 6,723' MD to change out motor on top drive and slip and cut drill line. TIH and began drilling ahead to 9,891' were we encountered a tight spot. Pumped sweep and continued ahead. Currently drilling with a bit depth of 10,028' MD with background gases around 65 units. Max Gas: 1013 Units Fluids: 0 bbl Fluid lost downhole. Geology: 60% Sandstone, 20% Coal, 10% Sand; 10% Tuff 07/5/2015 Drilled ahead to 10,165’ MD and pumped a tandem sweep. Continued drilling ahead to 10,447’ MD and pumped another sweep. Began short trip but well was flowing and gas reached 646 units. Weighted up mud and currently conducting a flow check. Max Gas: 1091 Units Fluids: 0 bbl Fluid lost downhole. Geology: 70% Sandstone, 30% Coal 07/6/2015 Weighted up mud to 10.2 ppg and well was still flowing. Decision was made to drill ahead to get out of coal. Made up a stand and began to rotate top drive when hydraulic fluid began leaking. Could not fix top drive and the decision was made to TOOH to the casing shoe. Currently changing out top drive. Max Gas: 651 Units Fluids: 0 bbl Fluid lost downhole. Geology: 70% Sandstone, 30% Coal 07/7/2015 Finished changing out the top drive. RIH until the bit reached outside of the casing shoe. Rotated and checked the torque. Continued to RIH to 8,650' MD and pumped a sweep. Currently RIH with a bit depth 8,840' MD at the time of the report. Max Gas: 451 Units Fluids: 0 bbl Fluid lost downhole. Geology: 70% Sandstone, 30% Coal 07/8/2015 RIH with bottoms up gas of 2527 units. Drilled ahead to 10,821' and pumped a sweep. Currently drilling ahead around 50 ft/hr with a bit depth of 11,170'. Background gas is around 55 units. Max Gas: 708 Units Fluids: 0 bbl Fluid lost downhole. Geology: 60% Siltstone, 20% Sandstone, 20% Coal 07/9/2015 Drilled ahead to 11,200 MD and TD'd well. Pumped a sweep and wiper tripped to casing shoe. Circulated until the wellbore cleaned up and picked up out of hole to the shoe with no issues. POOH to BHA at time of report. Max Gas: 2801 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Sandstone, 50% Coal 07/10/2015 Finished POOH and L/D BHA. Tested BOP and picked up Mad Pass BHA and ran in the hole with it. RIH to 6,751' MD. Slip and cut drill line and began rig service and replacing top drive. Currently changing out motor at time of report. Max Gas: 121 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Sandstone, 50% Coal 07/11/2015 Finished replacing the top drive motor. Continued to RIH to 8,961' fill pipe and continued to 11,145' MD and washed last stand down. Began mad passing up the hole. Currently mad passing up hole at 9,250' MD. Background gas is around 15 units. Max Gas: 2470 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Sandstone, 50% Coal 07/12/2015 Continued MAD passing to 7,600' MD. TOOH to shoe and flow checked the well. Pumped a dry job and TOOH and L/D pipe. Currently L/D BHA. Max Gas: 101 Units Fluids: 0 bbl Fluid lost downhole Geology: 50% Sandstone, 50% Coal 07/13/2015 Finished L/D BHA. M/U liner and began RIH with 4.5" production liner. M/U hanger and continued RIH with drill pipe to casing shoe and circulated bottoms up. RIH to 9,918' MD and circulated B/U. Continued to RIH to 11,171' MD and rigged up cement head. RIH to 11,198' MD. And circulated B/U. Circulating at time of report. Max Gas: 224 Units Fluids: 0 bbl Fluid lost downhole. Geology: 50% Sandstone, 50% Coal 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 0 5 10 15 20 25 30 35 40 45 50 55 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: Blossom 1 & Blossom 1 PB1 OPERATOR: Hilcorp Alaska, LLC MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: AK-XX-0902378615 Days vs. Depth 23 May 2015 Sperry SDL Arrived on Location LOCATION: Ninilchik Unit AREA: Kenai Peninsula Bourough STATE: Alaska SPUD: 24-May-2015 TD: 9-Jul-2015 Commenced 13.5" Surface Hole Section On Bot: 03:20 24 May 2015 TD Surface Hole Section 2506' MD, 1588' TVD Off Bot: 00:50 26 May 2015 Landed 10.75" Casing 2495' MD, 1585' TVD 28 May 2015 Commenced 9.875" Intermediate Hole Section On Bot: 15:54 30 May 2015 TD Intermediate Hole Section 6794' MD, 3415' TVD Off Bot: 18:25 05 June 2015 Landed 7.625" Casing 6794' MD, 3415' TVD 08 June 2015 Commenced 6.75" PB1 Production Hole Section On Bot: 15:23 10 June 2015 TD Production Hole Section 11200' MD, 7585' TVD Off Bot: 02:04 09 July 2015 Commenced 6.75" Production Hole Section On Bot: 10:35 01 July 2015 TD PB1 Production Hole Section 12098' MD, 8407' TVD Off Bot: 05:38 17 June 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Production #2 (side track) Difficulties experienced: 8900 Gas Chromatograph failed and had to be switched out, there was minimal data lost. Recommendations: Make sure the back up is always ready to go in case of a failure. Innovations and/or cost savings: N/A Saxon 169 Jacob Robertson 14-Jul-2015 What went as, or better than, planned: Our 9000 Gas Analyzer ran well the entire job. Good team work and handovers notes throughout the job. Blossom 1 Ninilchik Unit Hilcorp Alaska, LLC 0 -XX-0902378615 Alaska Surface Data Logging After Action Review Surface Data Logging Blossom 1 & Blossom 1 PB1 Hilcorp Alaska, LLC Baroid Saxon 169 -XX-0902378615 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/R 6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 23-May 110 8.75 175 34 48 23/43/49 9.2 116.0/82.0/25.0/22.0 2/0 3.0 0/96.7 -0.30 9.7 18.0 0.20/0.55 800 -P/U DP 24-May 1214 9.10 155 36 53 17/38/48 7.3 125.0/89.0/73.0/53.0 2/0 5.7 0/94.1 1.50 0.10 8.9 23.0 0.05/0.30 250 -Drilling Surface Interval 25-May 2464 9.30 187 44 62 22/39/49 6.9 150.0/106.0/88.0/64.0 2/0 7.1 0/92.7 1.00 -8.3 25.0 0/0.30 200 -Drilling Surface Interval 26-May 2506 9.25 60 27 27 8/13/18 7.1 81.0/54.0/42.0/28.0 2/0 6.8 0/93.0 0.25 0.05 8.6 25.0 0.05/0.35 150 -R/U to run 10 3/4" Casing 27-May 2506 9.25 60 27 27 8/13/18 7.1 81.0/54.0/42.0/28.0 2/0 6.8 0/93.0 0.25 0.05 8.6 25.0 0.05/0.35 150 160 N/D Diverter 28-May 2506 9.20 54 11 14 5/7/9 4.3 36.0/25.0/20.0/15.0 2/0 3.6 0/94.0 -0.50 10.2 -0.10/0.55 29000 -P/U DP 29-May 2506 9.20 61 13 17 6/8/10 4.5 43.0/30.0/24.0/18.0 1/2 3.6 0/94.0 0.25 0.50 10.5 1.5 0.45/2.50 29000 100 Slip and cut drill line 30-May 2775 9.25 55 13 18 6/9/12 4.4 44.0/31.0/26.0/19.0 1/2 4.2 0/93.5 1.00 0.60 10.4 1.5 0.20/1.80 28500 120 Drilling Intermediate Interval 31-May 3803 9.30 63 15 25 8/14/19 4.8 55.0/40.0/34.0/25.0 1/2 4.5 0/92.9 0.75 0.45 9.8 3.5 0.20/2.10 31500 180 Drilling Intermediate Interval 1-Jun 4886 9.40 52 13 20 6/12/19 4.9 460/33.0/28.0/20.0 1/2 5.5 0/92.0 0.25 0.35 9.3 6.0 0.15/1.40 31500 250 Drilling Intermediate Interval 2-Jun 5678 9.45 56 14 21 7/15/20 4.0 49.0/35.0/30.0/20.0 1/2 5.8 0/91.3 0.25 0.55 9.8 5.0 0.25/2.10 30500 80 Drilling Intermediate Interval 3-Jun 6166 9.45 61 18 23 6/13/20 3.8 59.0/41.0/33.0/24.0 1/2 5.7 0.8/91.0 0.25 0.60 9.6 4.5 0.30/2.10 31000 40 Drilling Intermediate Interval 4-Jun 6795 9.55 66 20 24 7/12/19 3.8 64.0/44.0/36.0/26.0 1/2 6.4 0.8/90.5 0.25 0.65 10.1 3.5 0.40/1.90 29000 40 TOOH 5-Jun 6795 9.50 70 17 23 6/13/19 4.0 57.0/40.0/33.0/24.0 1/2 6.4 1.0/90.2 0.10 0.45 9..8 3.5 0.30/1.70 30000 40 MAD Pass 6-Jun 6795 9.45 67 20 24 6/11/18 3.8 64.0/44.0/36.0/25.0 1/2 6 1.0/90.6 0.1 0.8 10.7 3.5 1.10/3.20 31000 40 MAD Pass 7-Jun 6795 9.35 65 16 21 5/9/16 3.6 53.0/37.0/30.0/21.0 1/2 5.1 1.0/91.4 0.1 0.6 9.8 3 0.35/1.80 31000 40 RIH w/ intermediate casing 8-Jun 6795 9.4 67 15 19 5/10/14 3.6 49.0/34.0/28.0/19.0 1/2 5.5 0.8/91.2 0.1 0.9 10.8 2.8 0.80/2.70 32000 80 Testing BOPs 9-Jun 6795 9.35 60 14 20 5/8/12 3.8 48.0/34.0/28.0/20.0 1/2 5.2 0.5/91.8 0.1 0.8 10.2 3 0.80/1.90 31000 80 RIH with 6 3/4" drilling assembly 10-Jun 7011 9.15 70 18 23 6/10/14 4.0 59.0/41.0/34.0/24.0 1/2 3.6 0.5/93.4 0.1 0.9 10.6 2 0.30/1.40 31000 120 Drilling Production Interval 11-Jun 7818 9.3 64 17 23 5/8/11 4.2 57.0/40.0/32.0/23.0 1/2 4.6 1.0/91.8 0.1 0.7 10.2 2 0.35/1.40 32000 160 Wiper Trip 12-Jun 8809 9.25 62 16 20 4/7/10 3.6 52.0/36.0/29.0/20.0 1/2 4.6 1.0/91.8 -0.55 10 2 0.50/1.70 33000 40 Wiper Trip 13-Jun 9801 9.3 58 16 19 4/7/10 3.7 51.0/35.0/28.0/20.0 1/2 4.8 1.0/91.6 -0.65 10 2.7 0.40/1.60 32000 80 Wiper Trip 14-Jun 10420 9.3 64 16 19 5/7/19 3.4 51.0/35.0/29.0/21.0 1/2 4.6 1.0/92.0 0.1 0.5 9.8 2.7 0.20/1.20 30000 80 Drilling Production Interval 15-Jun 11047 9.3 63 19 19 5/6/8 3.3 57.0/38.0/30.0/21.0 1/2 4.5 1.0/91.8 0.1 0.65 10.3 2.5 0.40/1.70 34000 60 Drilling Production Interval 16-Jun 11850 9.3 61 15 22 6/8/11 3.4 52.0/37.0/30.0/22.0 1/2 4.7 0.7/92.0 0.1 0.8 10.4 2.5 0.35/1.50 33000 200 RIH with singles 17-Jun 12100 9.2 58 15 21 6/8/10 3.2 51.0/36.0/29.0/21.0 1/2 3.9 0.5/92.9 0.1 0.35 9.6 2.5 0.20/1.10 33000 160 Working Pipe 18-Jun 12100 9.2 58 15 20 5/7/9 3.4 50.0/35.0/29.0/20.0 1/2 4 0.5/92.7 0.1 0.35 9.7 2.5 0.15/1.10 32000 80 Working Pipe 19-Jun 12100 9.25 59 16 21 5/7/9 3.2 53.0/37.0/30.0/21.0 1/2 4.3 0.5/92.6 0.10 0.2 9.2 2.5 0.10/0.80 32000 80 Working Pipe 20-Jun 12100 9.2 55 12 20 5/8/12 3.5 44.0/32.0/27.0/19.0 1/2 4.1 0.5/92.9 0.10 0.8 9.9 2.5 0.55/2.10 30500 160 Working Pipe 21-Jun 12100 9.20 54 12 19 5/8/12 3.3 43.0/31.0/26.0/19.0 1/2 4.0 0.5/93.0 0.10 1.00 10.4 2.5 0.80/2.40 30500 120 RIH w/ coil tubing 1-Jul 7517 9.2 57 14 23 6/8/10 3.9 51/37/31/23/7/5 1/2 3.9 .4/93.1 0.03 0.95 10.3 2 0.7/4.8 33000 3800 Drilling Production Interval 2-Jul 8339 9.4 53 15 21 4/6/8 4.0 51/36/29/20/5/4 1/2 5.2 .3/91.7 0.03 1.2 10.1 2.3 1/5 35000 4000 Drilling Production Interval 3-Jul 9456 9.45 59 19 22 4/6/9 3.4 60/41/33/22/6/4 1/2 6.1 1/90.5 0.03 1.9 10.1 2.5 1.65/5.9 30500 2500 TOH to casing shoe 4-Jul 9943 9.4 56 16 18 3/5/8 3.4 50/34/27/19/5/3 1/2 5.6 1/90.9 0.03 1.7 10 3.3 1.5/5.5 32000 2000 Drilling Production Interval 5-Jul 10447 9.85 55 16 21 4/7/10 3.1 53/27/29/20/6/4 1/2 7.3 1/89.2 0.03 1.2 9.6 3.5 1/4.2 31500 2400 Conducting flow check 6-Jul 10447 10.25 70 19 25 6/8/10 2.8 63/44/35/25/7/5 1/2 8.7 1/87.8 0.03 1.1 9.8 3.5 .9/4 32500 2000 Changing out top drive 7-Jul 10447 10.1 67 19 20 4/7/10 2.8 58/39/31/21/6/4 1/2 8.4 1/88.3 0.03 1 9.8 3.5 .8/3.6 30500 2000 Cond. Mud, Circulate 8-Jul 11055 10 56 16 19 4/6/8 3.2 51/35/28/19/5/4 1/2 8.1 1/88.6 0.025 0.7 9.5 3.5 .55/2.9 30000 1750 Drilling Production Interval 9-Jul 11200 10 55 16 20 5/7/10 3.1 52/36/29/21/6/4 1/2 8 .8/89 0.5 0.85 10 3.8 .7/3 28500 1300 POOH to test BOPs 10-Jul 11200 10.05 56 15 19 5/7/10 3.0 49/34/27/20/6/4 1/2 8.1 .8/88.9 0.25 0.9 10 3.5 .7/2.9 29500 1200 Repair Rig 11-Jul 11200 10 52 14 19 5/8/11 3.2 47/33/27/19/6/5 1/2 8 .5/89.2 0.15 0.8 9.8 3.3 .6/2.85 29000 900 MAD Pass 12-Jul 11200 10 55 14 22 7/10/13 3.0 50/36/30/22/7/5 1/2 7.8 .4/89.3 0.1 1 9.9 3.5 .9/3.6 31500 700 L/D BHA Casing Record Remarks 16" Conductor @ 110' MD, 110' TVD 10.75" Casing @ 2495' MD, 1585'TVD 7.625" Casing @ 6794' MD, 3415'TVD WELL NAME:LOCATION:Ninilchik Unit OPERATOR:AREA:Kenai Peninsula Borough MUD CO:STATE:Alaska RIG:SPUD:24-May-2015 SPERRY JOB:TD:9-Jul-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 HDBS QHC1GRC Milltooth 13.5"110 2506 2396 37.51 0.739 115.0 22 70 2150 550 1-1-CT-G-E-I-ER-TD Surface TD 2 200 2 HDBS MM65 PDC 9.875"2506 6794 4288 105.92 0.778 79.0 15 80 3050 530 1-1-CT-G-X-I-WT-BHA Intermediate TD 4 400 3 Varel V613PDUX 6.75"6794 12098 5304 149.39 0.557 55.0 9 80 3200 350 N/A PB1 Production BHA Lost in Hole 5 600 4 Varel V513PDHRU 6.75 7500 11200 3700 140.61 0.479 26.3 4 70 2495 335 1-2-WT-G-X-I-NO-TD Production TD Alaska RIG:Saxon 169 SPUD:24-May-2015 WELL NAME:Blossom 1 & Blossom 1 PB1 LOCATION:Ninilchik Unit OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO: SPERRY JOB:-XX-0902378615 TD:9-Jul-2015 Baroid STATE: B i t R e c o r d . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: - Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' -Maximum - Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs - Units* Casing Summary Lithology (%) C-2 - - Siltst - - TFABit Type Depth 18.0175 MBT (ppb Eq) Hours -- C-5n N/A Set AtSize Cly - N/A - Gas Summary 78' 78' 0' Max @ ft Current Minimum Depth Time: in - - state representative and then began picking up drill pipe and racking back. Finished mixing spud mud and function test solids N/A Picking up Drill Pipe Avg to (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson/ L. Toussant ShClyst - Sst SPP (psi) Gallons/stroke 0' 48 W OB 0.00 78' 0' 34 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max Weight Sd YP - 9.70 C-3 -- Cement - - - --- Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average N/A (max) Trip (max)(current) RPM ECD (ppg) ml/30min 9.2 0 pH Tools API FL control equipment. Finished picking up drill pipe and prepping to pick up Bottom hole assembly at time of report. 78' 100% Gas In Air=10,000 UnitsN/AConnection - Geology: N/A Fluids: 0 bbls Max Gas: N/A Bit # 3.08.758.75 Size Spud78' MWD Summary Rig Activity: N/A Saxon 169 Report For: - Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: @ Mud Data Morning Report Report # 1 Customer: Well: Area: Location: Rig: Depth Condition 23-May-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides N/ABackground - mg/l 800 Continued rigging up and began mixing spud mud. Completed function, time annular, and knife valve tests with Density (ppg) out (sec/qt) Viscosity Cor Solids . . * 24 hr Recap:Finished picking up drill pipe and heavy weight drill pipe. Made up Bottom Hole Assembly and tagged at 110' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids mg/l 250 0 8Background N/AN/A Avg Min % Chlorides Depth Condition 24-May-2015 23:59 Current Pump & Flow Data: 1834 Max ROP ROP (ft/hr) 2.93 @ Mud Data Morning Report Report # 2 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 83.1 Date: Bit # 5.79.108.85 Size Spud1214' Geology: No Samples Collected Fluids: 0 bbls Max Gas: 13 Units of midnight report. bottom hole assembly and ran in hole to bottom. Commenced directional drilling the 13.5" surface interval to 1214' MD at time Circulated bottoms up and pulled back out of hole to make up the remainder of the bottom hole assembly. Finished making up 78' 100% Gas In Air=10,000 Units0Connection 0 RPM ECD (ppg) ml/30min 2./0 0 pH Tools Directional API FL (max) Trip (max)(current) Average N/A Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 8.90 C-3 00 Cement Depth in / out PV 24 hr Max Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0' 53 WOB 0.00 78' 0' 36 R. Pederson/ L. Toussant ShClyst 549.3 Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Drilling Ahead Avg to (current) in 1226' 95.5 Circulated conductor with fresh water then displaced mud to 8.8 pounds per gallon Spud-Mud. Spud from 110' MD to 237' MD. 3 78' 1214' 1136' Max @ ft Current Minimum Depth Time: 296' 0 1202' Gas Summary 0 0 C-5n 13 Set AtSize Cly TFABit Type Depth 23.0155 MBT (ppb Eq) Hours 0 0 Siltst 0 0 542 185 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 2122 2678Maximum 932 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' 20321Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 4461 548 189 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 25.0187 MBT (ppb Eq) Hours 0 0 C-5n 139 Set AtSize Cly 1780' 0 1227' Gas Summary 1214' 2464' 1250' Max @ ft Current Minimum Depth Time: in 2241' 61.0 tandem sweeps; 10% increase in cuttings. Ran a wiper trip to jars with no complications. No fill, once back on bottom. Continued 28 Drilling Ahead Avg to (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson/ L. Toussant ShClyst 409.1 Sst SPP (psi) Gallons/stroke 0' 62 W OB 0.00 78' 0' 44 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max Weight Sd YP 0 8.30 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 6.9 0 pH Tools Directional API FL drilling to 1,971' MD, pumped 25 barrels of fresh water at 25 barrels weighted tandem sweeps; no increase in cuttings. Once 78' 100% Gas In Air=10,000 Units0Connection 0 Geology: No Samples Collected Fluids: 0 bbls Max Gas: 139 Units again, continued drilling ahead to 2,464' MD at time of midnight report. Bit # 7.19.30925.00 Size Spud2464' MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 167.1 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 3 Customer: Well: Area: Location: Rig: Depth Condition 25-May-2015 23:59 Current Pump & Flow Data: 1965 Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 30Background 0 mg/l 200 Drilled ahead to 1,226' MD, pumped 25 barrels of fresh water at 25 barrels weighted to 10.0 pounds per gallon Density (ppg) out (sec/qt) Viscosity Cor Solids . . * 24 hr Recap:Continued drilling ahead from 2464’ MD to surface TD of 2506’ MD and circulated hole clean. Tripped out of hole Density (ppg) out (sec/qt) Viscosity Cor Solids mg/l 150 0 36Background N/AN/A Avg Min % Chlorides Depth Condition 26-May-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 4 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 44.0 Date: Bit # 6.89.25925.00 Size Spud2506' Geology: No Samples Collected Fluids: 262 bbls Max Gas: 139 Units down bottom hole assembly, and rigged up for casing run. 2506’ MD. Pumped high viscosity marker sweep and circulated hole clean. Tripped out of hole from 2506’ MD, rigged down Serviced top drive, draw works, crown, and cleaned mud pump screens. Ran back in hole washing and reaming from 175’ MD to 78' 100% Gas In Air=10,000 Units0Connection 0 RPM ECD (ppg) ml/30min 7.1 0 pH Tools Directional API FL (max) Trip (max)(current) Average 30 Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 8.60 C-3 00 Cement Depth in / out PV 24 hr Max Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0' 27 WOB 0.00 78' 0' 27 R. Pederson/ L. Toussant ShClyst 101.0 Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Rigging up for casing Avg to (current) in 2495' 0.0 from 1200’ MD to 770’ MD and lost returns. Established full returns after some troubleshooting and pulled out of hole to 175’ MD. 28 2464' 2506' 42' Max @ ft Current Minimum Depth Time: 2506' 0 2498' Gas Summary 0 0 C-5n 66 Set AtSize Cly TFABit Type Depth 25.060 MBT (ppb Eq) Hours 0 0 Siltst 0 0 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 6628 10278Maximum 4274 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing 6393Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 829 10.75'' Units* Casing Summary Lithology (%) C-2 109 0 Siltst 0 0 TFABit Type Depth 25.060 MBT (ppb Eq) Hours 0 0 C-5n 40 Set AtSize Cly 0 2498' Gas Summary 2506' 2506' 0' Max @ ft Current Minimum Depth Time: in 2495' lost 12 barrels to well during trip. Once on bottom we rigged up cement head and circulated/conditioned mud before pumping 6 N/D Diverter Avg to (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson/ L. Toussant ShClystSst SPP (psi) Gallons/stroke 0' 27 W OB 0.00 78' 0' 27 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max Weight Sd YP 13 8.60 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 32 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 7.1 0 pH Tools API FL cement job. Nippling down diverter at time 2495' 78' 100% Gas In Air=10,000 Units0Connection 11 Geology: No Samples Collected Fluids Lost: 95 bbls Max Gas: 40 Units Bit # 6.89.259.25 Size Spud2506' MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 5 Customer: Well: Area: Location: Rig: Depth Condition 27-May-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 3Background 0 mg/l 150 Finish rigging up to run casing, tested float equipment, and began running in hole with 10 3/4" casing to 2,495' MD; Density (ppg) out (sec/qt) Viscosity Cor Solids . . * 24 hr Recap:Began nippling up Blowout Preventer, hauled spud mud off to G&I, cleaned pits, and started building a 300 barrel Density (ppg) out (sec/qt) Viscosity Cor Solids mg/l 29000 0 0Background N/AN/A Avg Min % Chlorides Depth Condition 28-May-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) @ Mud Data Morning Report Report # 6 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary Rig Activity: N/A Saxon 169 Report For: Date: Bit # 3.69.209.25 Size KCI/Polymer2506' Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 0 Units Preparing to pick up drill pipe at time of midnight report. 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 RPM ECD (ppg) ml/30min 4.3 0 pH Tools API FL (max) Trip (max)(current) Average 0 Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.20 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 2428' 14 WOB 0.00 78' 2506' 11 S. Hauck/ L. Toussant ShClystSst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 BOP's Avg to (current) in 0' batch of new mud. Finished nippling up Blowout Preventer and completed shell test before conducting Blowout Prevention Test. 0 2506' 2506' 0' Max @ ft Current Minimum Depth Time: 0 0' Gas Summary 0 0 C-5n 0 Set AtSize Cly TFABit Type Depth 54 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 0 L-80 0Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing L-80 0Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 0 10.75'' Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 1.561 MBT (ppb Eq) Hours 0 0 C-5n 0 Set AtSize Cly 0 0' Gas Summary 2506' 2506' 0' Max @ ft Current Minimum Depth Time: in 0' 4.5” drill pipe down to 2390’; tagged cement and began circulating bottoms up. Circulated at idle, over-boarding thick spud mud 0 Slip & Cut Drill Line Avg to (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 S. Hauck / L. Toussant ShClystSst SPP (psi) Gallons/stroke 2428' 17 W OB 0.00 78' 2506' 13 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.50 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 4.5 0 pH Tools API FL and watering back. Once mud diluted back enough to stay on shakers we increased rate to 190 gallons per minute. Circulated 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 0 Units hole clean and then slip and cut drill line. Bit # 3.69.209.20 Size KCI/Polymer2506' MWD Summary Rig Activity: N/A Saxon 169 Report For: Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: @ Mud Data Morning Report Report # 7 Customer: Well: Area: Location: Rig: Depth Condition 29-May-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 0 0Background 0 mg/l 29000 0 0 Finished testing BOP's and performed casing test to 2,700 psi; everything went well. Ran in hole while picking up Density (ppg) out (sec/qt) Viscosity Cor Solids . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing L-80 93428 80 Maximum 0 10 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 731 10.75'' 425 140 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 1.561 MBT (ppb Eq) Hours 0 0 C-5n 12 2779' Set AtSize Cly 2781' 4 2506' Gas Summary 2506' 2775' 269' Max @ ft Current Minimum Depth Time: in 2723' 0.0 shallow tested MWD tools, ran in hole to 2322’ MD, lined up pumps, and started drilling out float equipment and shoe at 2,491' MD, 5 Drilling Ahead Avg to2506' (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 S. Hauck / L. Toussant ShClyst 322.0 Sst SPP (psi) Gallons/stroke 2428' 17 W OB 0.00 78' 2506' 13 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.50 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 5 Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 4.5 0 pH Tools Directional, Gamma, EWR, Nuke API FL displaced well over to 9.2 pounds per gallon: 6% KCL/PHPA mud, performed F.I.T. test at 12.0 EMW, and drilled ahead into 2495' 78' 100% Gas In Air=10,000 Units0Connection 5 0 Geology: 80% Sand, 10% Siltstone, 5% Claystone, 5% Sandstone Fluids Lost: 0 bbls Max Gas: 12 Units intermediate section until midnight depth of 2775’ MD. Bit # 3.69.309.20 Size KCI/Polymer MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 166.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 8 Customer: Well: Area: Location: Rig: Depth Condition 30-May-2015 23:59 Current Pump & Flow Data: 1088 Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 0 7Background 0 mg/l 29000 0 0 Finished slipping and cutting the drill line, pulled out of the hole to surface, picked up directional tools, shallow Density (ppg) out (sec/qt) Viscosity Cor Solids 2 HDBS MM 65 PDC 9.875 0.778 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Ran a wiper trip back to the shoe and picked up 12 joints of heavy weight drill pipe. Ran back into the hole after the Density (ppg) out (sec/qt) Viscosity Cor Solids 1024' mg/l 31500 3803' 0 0 0 7Background N/AN/A Avg Min % Chlorides 0 Depth Condition 31-May-2015 23:59 Current Pump & Flow Data: 1690 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 9 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 163.4 Date: Bit # 4.59.309.30 Size KCI/Polymer3803' Geology: 50% Sand, 30% Claystone, 20% Siltstone Fluids Lost: 0 bbls Max Gas: 83 Units shakers. Circulated hole clean and continued to run into hole to 3587' MD, drilled ahead to 3745' MD, pumped Hi-Vis with WALL- work through on the elevators. Ran back in hole to 2719' MD, pumped HI-Vis WALL-NUT sweep; 40% increase in cuttings at Drilled ahead to 3583' MD and short tripped back to shoe; tight spots at 3522' MD, 3,026' MD, and 2952' MD that we were able to 2495' 78' 100% Gas In Air=10,000 Units44Connection 30 0 RPM ECD (ppg) ml/30min 4.8 0 pH Tools Directional, Gamma, EWR, Nuke API FL (max) Trip (max)(current) Average 0 Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 9.80 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 2428' 25 WOB 0.00 78' 2506' 15 S. Hauck / L. Toussant ShClyst 361.0 Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Drilling Ahead Avg to2779' (current) in 3773' 100.0 wiper trip and continued drilling ahead to 3377' MD. Pumped a Hi-Vis sweep (230 vis) with no increase in cuttings at shakers. 19 NUT & CON-DET sweep; cuttings increased 60% at shakers. 2775' 3804' 1029' Max @ ft Current Minimum Depth Time: 2849' 0 2761' Gas Summary 5 0 C-5n 83 3803' Set AtSize Cly TFABit Type Depth 3.563 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 495 169 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 4668 L-80 15990 50 Maximum 0 20 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing L-80 58193 30 Maximum 0 50 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 15439 10.75'' 0 180 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 6.054 MBT (ppb Eq) Hours 5 0 C-5n 431 4886' Set AtSize Cly 3898' 7 3774' Gas Summary 3804' 4886' 1082' Max @ ft Current Minimum Depth Time: 10 in 4709' 0.0 shakers. Started a short trip back to the shoe on elevators and serviced rig. Ran in hole to bottom with no issues or fill. Continued 75 W iper Trip Avg to3803' (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 S. Hauck / L. Toussant ShClyst 228.9 Sst SPP (psi) Gallons/stroke 2428' 20 W OB 0.00 78' 2506' 13 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.30 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 10 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 4.9 0 pH Tools Directional, Gamma, EWR, Nuke API FL drilling ahead to 4,886' MD, pumped another high viscosity sweep with walnut; 60% increase in cuttings at shakers. Wiper tripped 2495' 78' 100% Gas In Air=10,000 Units153Connection 10 0 Geology: 50% Siltstone, 30% Sand, 10% Claystone, 10% Tuff Fluids Lost: 0 bbls Max Gas: 431 Units up to 4,504' MD, circulated bottoms up, and ran back into the hole with no issues. Bit # 5.59.409.30 Size KCI/Polymer4886' MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 180.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 10 Customer: Well: Area: Location: Rig: Depth Condition 1-Jun-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 0 5Background 0 mg/l 31500 4886' 0 0 Drilled ahead to 4,513' MD, pumped a high viscosity and a low viscosity sweep; 15% increase in cuttings at the Density (ppg) out (sec/qt) Viscosity Cor Solids 2380'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Drilled to 5,259' MD and pumped a low viscosity, low weight sweep; followed by a high viscosity, high weight sweep; Density (ppg) out (sec/qt) Viscosity Cor Solids 3172' mg/l 30500 5678' 0 0 0 30Background 993.001147.00 Avg Min % Chlorides 0 Depth Condition 2-Jun-2015 23:59 Current Pump & Flow Data: 2143 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 11 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 2680.00 Saxon 169 Report For: 97.0 Date: Bit # 5.89.459.45 Size KCI/Polymer5678' Geology: 60% Sand, 20% Siltstone, 10% Claystone, 10% Coal Fluids Lost: 0 bbls Max Gas: 297 Units midnight report. and had a 15% increase of cuttings at the shakers. Serviced the rig and ran into the hole to drill ahead; drilling at 5,678' at time of 2495' 78' 100% Gas In Air=10,000 Units188Connection 10 0 RPM ECD (ppg) ml/30min 4.0 0 pH Tools Directional, Gamma, EWR, Nuke API FL (max) Trip (max)(current) Average 0 Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 9.80 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 2428' 21 WOB 0.00 78' 2506' 14 S. Hauck / D. Yessak ShClyst 10 236.0 Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Drilling Ahead Avg to4886' (current) in 5616' 96.1 30% increase in cuttings at shakers. Short tripped to 4,138' MD running into a couple of tight spots. Pumped a high viscosity sweep 66 4886' 5678' 792' Max @ ft Current Minimum Depth Time: 5203' 5 5187' Gas Summary 5 0 C-5n 297 5678' Set AtSize Cly TFABit Type Depth 5.056 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 522 180 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 13097 L-80 42120 60 Maximum 68 20 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing L-80 31478 70 Maximum 61 20 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 10138 10.75'' 522 180 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 4.561 MBT (ppb Eq) Hours 0 0 C-5n 227 6166' Set AtSize Cly 6002' 0 6000' Gas Summary 5678' 6166' 488' Max @ ft Current Minimum Depth Time: in 6001' 58.0 . Drilled to 5,999' MD, pumped another high viscosity sweep and had a 25% increase in cuttings. Then we pumped low viscosity 39 drilled ahead to 6095' MD, worked pipe and continued drilling ahead to 6127', pumped a high viscosity sweep and observed a minimal increase in cuttings. Drilling Ahead Avg to5678' (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 S. Hauck / D. Yessak ShClyst 10 202.0 Sst SPP (psi) Gallons/stroke 2428' 23 W OB 0.00 78' 2506' 18 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.60 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.8 0 pH Tools Directional, Gamma, EWR, Nuke API FL sweep with low weight followed by a high viscosity sweep with high weight and had a 60% increase in cuttings. Circulated hole 2495' 78' 100% Gas In Air=10,000 Units277Connection 0 Geology: 70% Sand, 20% Siltstone, 10% Coal Fluids Lost: 0 bbls Max Gas: 277 Units viscosity sweep with an increase of 15% at bottoms up and a 50% increase at surface to surface. Ran in hole to bottom and drilled clean and short tripped out of hole to 4,888' MD encountering multiple tight spots. Serviced the rig and pumped another high Bit # 5.79.459.45 Size KCI/Polymer6166' MWD Summary 95% Rig Activity: 1450.00 Saxon 169 Report For: 72.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 12 Customer: Well: Area: Location: Rig: Depth Condition 3-Jun-2015 23:59 Current Pump & Flow Data: 2022 Max ROP ROP (ft/hr) 1172.001356.00 Avg Min % Chlorides 0 11Background 0 mg/l 31000 6166' 0 0 Continued drilling ahead to 5,740' MD, pumped a high viscosity sweep and observed a 25% increase in cuttings. Density (ppg) out (sec/qt) Viscosity Cor Solids 3660'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Drilled to 6,433' MD, pumped a high viscosity sweep, and had a 20% increase in cuttings at shakers. Short tripped Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 29000 6795' 0 0 0 2Background 1437.001612.00 Avg Min % Chlorides 0 Depth Condition 4-Jun-2015 23:59 Current Pump & Flow Data: 1918 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 13 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 1853.00 Saxon 169 Report For: 74.0 Date: Bit # 6.49.559.50 Size KCI/Polymer6795' Geology: 40% Sand, 40% Siltstone, 20% Coal Fluids Lost: 0 bbls Max Gas: 123 Units hole to 4000' MD where we will pump another tandem sweep. the hole section was called as total depth. Pumped a high viscosity sweep showing 10% returns at the shakers. Took out of hole Pumped a high viscosity sweep while drilling ahead and had a 40% increase in cuttings at the shakers. Drilled to 6,795' MD where with a 50% increase in cuttings at the shakers. Serviced rig, ran in hole to bottom, and continued drilling ahead to 6,633' MD. 2495' 78' 100% Gas In Air=10,000 Units107Connection 20 0 RPM ECD (ppg) ml/30min 3.8 0 pH Tools Directional, Gamma, EWR, Nuke API FL (max) Trip (max)(current) Average 0 Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.10 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 2428' 24 WOB 0.00 78' 2506' 20 S. Hauck / D. Yessak ShClyst 222.0 Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Taking out of hole Avg to6166' (current) in 6181' 0.0 to 5,999' MD with no over pull, and pumped tandem sweeps; low viscosity, low weight followed by a high viscosity, high weight 39 to 5,649' MD and pumped a 50 barrel tandem sweep; 25 barrels of a Low viscosity, low weight sweep, chased by 25 barrels of a high viscosity, high weight sweep; showing a 100% increase in cuttings followed by a 200% increase in cuttings. Taking out of 6166' 6795' 629' Max @ ft Current Minimum Depth Time: 6449' 7 6169' Gas Summary 0 0 C-5n 123 6795' Set AtSize Cly TFABit Type Depth 3.566 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 528 180 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 9310 L-80 20180 40 Maximum 23 40 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing L-80 0Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 0 10.75'' 525 180 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 3.570 MBT (ppb Eq) Hours 0 0 C-5n 0 6795' Set AtSize Cly 0 0' Gas Summary 6795' 6795' 0' Max @ ft Current Minimum Depth Time: in 0' and began taking out on elevators to 3,022' MD, back reaming to 3,010' MD. Once inside of the casing we circulated a bottoms up 0 an increase in 25% of cuttings at the shakers. Mad Pass Logging Avg to6166' (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 S. Hauck / D. Yessak ShClystSst SPP (psi) Gallons/stroke 2428' 23 W OB 0.00 78' 2506' 17 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.80 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 45 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 4.0 0 pH Tools Directional, Gamma, EWR, Nuke API FL and observed a 10% increase in cuttings. Continued taking out of hole to bottom hole assembly, pulled sources, 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 45 Units on bottom, we observed a 50% increase in cuttings. Pumped a sweep once pumps were up and observed the sweep to have downloaded/uploaded MWD tool, and installed sources. Started running in hole to bottom for Mad Pass logs in open hole. Once Bit # 6.49.509.45 Size KCI/Polymer6795' MWD Summary 95% Rig Activity: Saxon 169 Report For: Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 14 Customer: Well: Area: Location: Rig: Depth Condition 5-Jun-2015 23:59 Current Pump & Flow Data: 2101 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 0Background 0 mg/l 30000 6795' 0 0 Took out of hole on elevators to 4200' MD and pumped another 50 barrel tandem sweep. Circulated the hole clean Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Continued to Mad pass to 6002' MD and pumped a high viscosity sweep; observing a 10% increase in cuttings at Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 31000 6795' 0 0 0 0Background Avg Min % Chlorides 0 Depth Condition 6-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 15 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Date: Bit # 6.09.459.40 Size KCI/Polymer6795' Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 9 Units and pumped another high viscosity sweep. Currently at 2,900' and mad passing up the hole at time of reporting. 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 RPM ECD (ppg) ml/30min 3.8 0 pH Tools API FL (max) Trip (max)(current) Average 45 Mud Type Lst Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.70 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 2428' 24 WOB 0.00 78' 2506' 20 S. Hauck / D. Yessak ShClystSst Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Mad Pass Logging Avg to (current) in 6794' the shakers. Continued Mad passing to 5500' MD and pumped a tandem sweep. Continued to Mad pass up the hole to 3525' MD 7 6795' 6795' 0' Max @ ft Current Minimum Depth Time: 4 6794' Gas Summary 0 0 C-5n 9 Set AtSize Cly TFABit Type Depth 3.567 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 1569 L-80 389Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 16.00'' Surface Casing L-80 63Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 14 10.75'' 387 132 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 3.065 MBT (ppb Eq) Hours 0 0 C-5n 9 Set AtSize Cly 0 6794' Gas Summary 6795' 6795' 0' Max @ ft Current Minimum Depth Time: in 6794' well; no increase or decrease. Pulled out of hole to bottom hole assembly, removed sources, downloaded MWD tool, finished 6 Running Casing Avg to (current) TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 S. Hauck / D. Yessak ShClystSst SPP(psi) Gallons/stroke 2428' 21 W OB 0.00 78' 2506' 16 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.80 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.6 0 pH Tools API FL laying down bottom hole assembly, checked flow, cleaned stack, changed rams, and tested for casing run. Rigged up Weatherford 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 9 Units surface to surface to circulate out bubble then continued running on hole at time of morning report. casing equipment and held a pre job safety meeting before starting to run 7 5/8 casing. Ran in hole to 2474’ MD and circulated a Bit # 5.19.359.35 Size KCI/Polymer6795' MWD Summary 95% Rig Activity: Saxon 169 Report For: Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 16 Customer: Well: Area: Location: Rig: Depth Condition 7-Jun-2015 23:59 Current Pump & Flow Data: 242 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 0Background 0 mg/l 31000 6795' 0 0 Continued to Mad pass to 2612' MD and pumped a tandem sweep. Pulled up into the casing and flow checked the Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Finished running the 7 5/8" casing down hole with no issues, and pumped a surface to surface circulation. Rigged Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 31000 6795' 0 0 0 0Background Avg Min % Chlorides 0 Depth Condition 8-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 17 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Date: Bit # 5.19.409.50 Size KCI/Polymer6795' Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 9 Units reporting. Installed well head pack off, changed out rams on blow out preventer and began pressure testing blow out preventer at time of 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 RPM ECD (ppg) ml/30min 3.4 0 pH Tools API FL (max) Trip (max)(current) Average 0 Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.80 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 2428' WOB 0.00 78' 2506' 15 S. Hauck / D. Yessak ShClystSst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Testing B.O.P.'s Avg to 29.7 (current) in 6794' down the Volant tool, rigged up cement head, and continued to circulate. Pumped Cement, and then rigged down cement head. 1 6795' 6795' 0' Max @ ft Current Minimum Depth Time: 0 6794' Gas Summary 0 0 C-5n 9 Set AtSize Cly TFABit Type Depth 2.867 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 205 L-80 1563Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Successfully pressure tested the blow out preventer. Picked up enough singles to reach total depth and racked Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 31000 6795' 0 0 0 0Background Avg Min % Chlorides 0 Depth Condition 9-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 18 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: Date: Bit # 5.29.359.36 Size 3 Varel V613PDUX KCI/Polymer 6795' 6795' Geology: No Samples Collected Fluids Lost: 0 bbls Max Gas: 0 Units 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 RPM ECD (ppg) ml/30min 3.8 0 pH Tools API FL (max) Trip (max)(current) Average 0 Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.20 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 2428' 20 WOB 0.00 78' 2506' 14 S. Hauck / D. Yessak ShClystSst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Running in hole Avg to 29.7 (current) 6.75 0.557 in 0' them back. Picked up BHA, MWD tools, mud motor, and began running in hole. 0 6795' 6795' 0' Max @ ft Current Minimum Depth Time: 0 0' Gas Summary 0 0 C-5n 0 Set AtSize Cly TFABit Type Depth 3.060 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 0 L-80 0Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Finished running into the hole and made up cuttings bed impellers every other stand. Ran in hole to 6480' MD and Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 31000 6795' 0 0 0 8Background Avg Min % Chlorides 0 Depth Condition 10-Jun-2015 23:59 Current Pump & Flow Data: 2504 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 19 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 67.0 Date: Bit # 3.69.159.10 Size 3 Varel V613PDUX KCI/Polymer 6795' 7011' Geology: 50% Siltstone, 40% Claystone, 10% Sand Fluids Lost: 0 bbls Max Gas: 61 Units a F.I.T. test to 12.0 pounds per gallon mud weight equivalent; passed. Continued drilling ahead at time of midnight reporting. the well to 9.1 pounds per gallon mud while drilling out cement. Drilled to 6815' MD, circulated bottoms up, and conducted 2495' 78' 100% Gas In Air=10,000 Units28Connection 0 RPM ECD (ppg) ml/30min 4.0 0 pH Tools Directional, Gamma, Res API FL (max) Trip (max)(current) Average 0 Mud Type Lst 50 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.60 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 216' 2428' 23 7011' WOB 0.00 78' 2506' 18 R. Pederson / D. Yessak ShClyst 7006.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Drilling Ahead Avg to6795' 29.7 (current) 6.75 0.557 in 6913' 99.0 circulated surface to surface while rigging up for casing test; test passed. Continued running in hole to 6631' MD and displaced 20 6795' 7011' 216' Max @ ft Current Minimum Depth Time: 193' 5 6804' Gas Summary 0 0 C-5n 61 7011' Set AtSize Cly TFABit Type Depth 2.070 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 340 119 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 3057 L-80 9378 10 40 Maximum 43 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 30064 20 60 Maximum 26 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 5093 10.75'' 0 119 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.064 MBT (ppb Eq) Hours 0 0 C-5n 224 7818' Set AtSize Cly 7059' 5 7075' Gas Summary 7011' 7818' 807' Max @ ft Current Minimum Depth Time: in 7526' 0.0 tandem low viscosity/high viscosity sweep. Continued drilling ahead to 7,818’ MD and pumped another tandem sweep. Circulated 35 W iper Trip Avg to7011' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson / D. Yessak ShClyst 132.0 Sst SPP(psi) Gallons/stroke 216' 2428' 23 7011' W OB 0.00 78' 2506' 17 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.20 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 20 Intermediate Casing Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 4.2 0 pH Tools Directional, Gamma, Res, Mud Motor API FL the hole clean and began pulling out of hole for a wiper trip. 2495' 78' 100% Gas In Air=10,000 Units93Connection 0 Geology: 60% Claystone, 20% Sand, 20% Siltstone Fluids Lost: 0 bbls Max Gas: 224 Units Bit # 4.69.309.23 Size 3 Varel V613PDUX KCI/Polymer 6795' 7818' MWD Summary 95% Rig Activity: Saxon 169 Report For: 76.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 20 Customer: Well: Area: Location: Rig: Depth Condition 11-Jun-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 0Background 0 mg/l 32000 6795' 0 0 Drilled ahead to 4,178’ MD and pumped a high viscosity sweep. Continued drilling to 7,468’ MD and pumped a Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Wiper tripped to 6,730' MD, serviced the rig, and ran back into the hole to continue drilling ahead. Drilled to 8,315' MD Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 33000 6795' 0 0 0 6Background Avg Min % Chlorides 0 Depth Condition 12-Jun-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 21 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 85.0 Date: Bit # 4.69.259.25 Size 3 Varel V613PDUX KCI/Polymer 6795' 8809' Geology: 50% Sand, 20% Sandstone, 10% Siltstone, 10% Claystone, 10% Tuff Fluids Lost: 0 bbls Max Gas: 234 Units increase in cuttings. Circulated the hole clean and began wiper tripping from 8809' MD. 2495' 78' 100% Gas In Air=10,000 Units234Connection 10 0 RPM ECD (ppg) ml/30min 3.6 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max) Trip (max)(current) Average 0 Mud Type Lst 20 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.00 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 2014' 2428' 20 8809' WOB 0.00 78' 2506' 16 R. Pederson / D. Yessak ShClyst 125.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Wiper Trip Avg to7818' 29.7 (current) 6.75 0.557 10 in 8702' 0.0 and pumped a high viscosity sweep. Continued drilling ahead to 8,809’ MD and pumped a tandem sweep; observed a 10% 70 7818' 8809' 991' Max @ ft Current Minimum Depth Time: 8446' 7 8535' Gas Summary 0 0 C-5n 425 8809' Set AtSize Cly TFABit Type Depth 2.062 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 0 0 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 11080 L-80 54309 50 Maximum 58 10 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 96240 40 Maximum 231 20 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 22738 10.75'' 0 0 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.758 MBT (ppb Eq) Hours 0 0 C-5n 786 9801' Set AtSize Cly 9504' 7 9358' Gas Summary 8809' 9801' 992' Max @ ft Current Minimum Depth Time: in 9206' 0.0 Continued drilling ahead to 9,801' MD and pumped a tandem sweep. Started wiper tripping to the shoe and pulled out of hole to 161 W iper Trip Avg to8809' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson / D. Yessak ShClyst 192.0 Sst SPP(psi) Gallons/stroke 3006' 2428' 19 9801' W OB 0.00 78' 2506' 16 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.00 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 40 Intermediate Casing Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.7 0 pH Tools Directional, Gamma, Res, Mud Motor API FL 8.828' MD. Pulled to 7,500' MD on elevators and pumped out of the hole to 7,400' MD. 2495' 78' 100% Gas In Air=10,000 Units325Connection 25 Geology: 40% Sandstone, 40% Sand, 20% Siltstone Fluids Lost: 0 bbls Max Gas: 786 Units Bit # 4.89.309.30 Size 3 Varel V613PDUX KCI/Polymer 6795' 9801' MWD Summary 95% Rig Activity: Saxon 169 Report For: 85.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 22 Customer: Well: Area: Location: Rig: Depth Condition 13-Jun-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 5Background 4 mg/l 32000 6795' 0 0 W iper tripped to 7,753’ MD and ran back to bottom. Drilled to 9,305' MD and pumped a high viscosity sweep. Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Finished pulling out to shoe and flow checked the well; no flow/losses. Ran back into the hole to 9,690' MD and then Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 30000 6795' 0 0 4 100Background Avg Min % Chlorides 0 Depth Condition 14-Jun-2015 23:59 Current Pump & Flow Data: 2468 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 23 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 47.0 Date: Bit # 4.69.259.30 Size 3 Varel V613PDUX KCI/Polymer 6795' 10420' Geology: 40% Sandstone, 30% Sand, 20% Coal, 10% Siltstone Fluids Lost: 0 bbls Max Gas: 1808 Units Note: We encountered the 1808 Units from bottoms up, after running in hole from the 9801' MD Wiper Trip. Continue to drill ahead at 10,420' MD at time of reporting. viscosity sweep and drilled ahead to 10,202' MD to pump another high viscosity sweep; observed a 50% increase in cuttings. 2495' 78' 100% Gas In Air=10,000 Units482Connection 22 RPM ECD (ppg) ml/30min 3.4 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max) Trip (max)(current) Average 0 Mud Type Lst 40 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 9.80 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 3625' 2428' 19 10420' WOB 0.00 78' 2506' 16 R. Pederson / D. Yessak ShClyst 20 95.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Drilling Ahead Avg to9801' 29.7 (current) 6.75 0.557 in 9804' 48.0 washed and reamed down to 9,801' MD. Continued drilling ahead 10,025' MD and experienced high torque. Pumped a high 150 9801' 10420' 619' Max @ ft Current Minimum Depth Time: 10371' 4 9802' Gas Summary 0 0 C-5n 1808 10420' Set AtSize Cly TFABit Type Depth 2.764 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 322 110 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 16643 L-80 211005 30 Maximum 0 10 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 124461 20 Maximum 0 60 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 35454 10.75'' 343 117 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.563 MBT (ppb Eq) Hours 0 0 C-5n 5496 11047' Set AtSize Cly 10894' 8 10854' Gas Summary 10420' 11047' 627' Max @ ft Current Minimum Depth Time: in 10855' 60.0 clean, pulled 1 stand and flow-checked the well; everything went well. Pulled out of hole to 9,734' MD with no issues, and then ran 261 Drilling Ahead Avg to10420' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson / D. Yessak ShClyst 105.0 Sst SPP(psi) Gallons/stroke 4252' 2428' 19 11047' WOB 0.00 78' 2506' 19 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.30 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 20 Intermediate Casing Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.3 0 pH Tools Directional, Gamma, Res, Mud Motor API FL back in hole picking up 10 singles. Reached bottom and washed down the last stand. After the trip, the hole unloaded mostly fine 2495' 78' 100% Gas In Air=10,000 Units0Connection 146 Geology: 60% Siltstone, 20% Sand, 20% Sandstone Fluids Lost: 0 bbls Max Gas: Units coal after circulating bottoms up. Continue drilling ahead at 11,047’ MD. Bit # 4.59.309.29 Size 3 Varel V613PDUX KCI/Polymer 6795' 11046' MWD Summary 95% Rig Activity: Saxon 169 Report For: 52.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 24 Customer: Well: Area: Location: Rig: Depth Condition 15-Jun-2015 23:59 Current Pump & Flow Data: 2739 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 110Background 13 mg/l 34000 6795' 0 0 Drilled ahead to 10,854' MD and pumped a tandem sweep, followed by a high viscosity sweep. Circulated the hole Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Drilled ahead to 11,300' MD and pumped a high viscosity sweep; observed a 20% increase in cuttings. Continued Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 33000 6795' 0 0 11 8Background Avg Min % Chlorides 0 Depth Condition 16-Jun-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 25 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 64.0 Date: Bit # 4.79.309.27 Size 3 Varel V613PDUX KCI/Polymer 6795' 11850' Geology: 40% Siltstone, 30% Coal, 20% Sand, 10% Sandstone Fluids Lost: 0 bbls Max Gas: 1995 Units MD, 10,902' MD; pulled up to 10,793' MD and began picking up enough singles to reach newly proposed TD. cuttings. Circulated the hole clean and began to pull out of the hole for a wiper trip. Tight spots at 11,050' MD - 11,041' MD, 10,994' 2495' 78' 100% Gas In Air=10,000 Units320Connection 68 RPM ECD (ppg) ml/30min 3.4 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max) Trip (max)(current) Average 35 Mud Type Lst 10 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.40 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 5055' 2428' 22 11850' WOB 0.00 78' 2506' 15 R. Pederson / S. Barber ShClyst 30 125.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 Wiper Trip Avg to11047' 29.7 (current) 6.75 0.557 in 11208' 0.0 drilling ahead to 11,850' MD and pumped a tandem sweep; observed the sweep to come back on time with a 200% increase in 177 11047' 11850' 803' Max @ ft Current Minimum Depth Time: 11359' 7 11610' Gas Summary 0 0 C-5n 1995 11850' Set AtSize Cly TFABit Type Depth 2.561 MBT (ppb Eq) Hours 6 0 Siltst 7 0 10.75'' 0 0 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 25619 L-80 165292 20 Maximum 68 40 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 75758 70 Maximum 509 30 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 6398 10.75'' 281 116 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 21 0 TFABit Type Depth 2.558 MBT (ppb Eq) Hours 0 0 C-5n 758 12100' Set AtSize Cly 12043' 8 11937' Gas Summary 11850' 12100' 250' Max @ ft Current Minimum Depth Time: in 11851' 0.0 before the hole cleaned up and we were able to drill ahead. Drilled to 12,098' MD, noticed an increase in torque, tried to back ream 37 W orking Pipe Avg to11850' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson / S. Barber ShClyst 130.0 Sst SPP(psi) Gallons/stroke 5303' 2428' 21 12100' WOB 0.00 78' 2506' 15 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.60 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.2 0 pH Tools Directional, Gamma, Res, Mud Motor API FL up but became stuck. Pumped a high viscosity sweep; no increase in cuttings. Continue to free the pipe by pumping sweeps, 2495' 78' 100% Gas In Air=10,000 Units758Connection 22 Geology: 70% Sand, 10% Siltstone Fluids Lost: 0 bbls Max Gas: 758 Units working the pipe, and jarring at time of report. Bit # 3.99.209.25 Size 3 Varel V613PDUX KCI/Polymer 6795' 12100' MWD Summary 95% Rig Activity: Saxon 169 Report For: 86.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 26 Customer: Well: Area: Location: Rig: Depth Condition 17-Jun-2015 23:59 Current Pump & Flow Data: 1973 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 75Background 2 mg/l 33000 6795' 0 0 Finished running into the hole, tagged 35' of fill and circulated a bottoms up. Circulated a surface to surface before Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 12879Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 1123 10.75'' Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.558 MBT (ppb Eq) Hours 0 0 C-5n 2226 Set AtSize Cly 0' 4 12098' Gas Summary 12098' 12098' 0' Max @ ft Current Minimum Depth Time: in 12098' 0.0 only get to 2200' MD. Rigged up circulating equipment in order to pump E-line down but could not circulate. Rigged down E-line 43 pump truck at time of report. R/U Schlumberger Avg to 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson / S. Barber ShClyst 0.0 Sst SPP(psi) Gallons/stroke 5303' 2428' 20 12098' WOB 0.00 78' 2506' 15 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.70 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.4 0 pH Tools API FL and worked pipe in hopes to establish circulation with no luck. Rigged up and ran into the hole with the E-line free point tool but 2495' 78' 100% Gas In Air=10,000 Units0Connection 0 Geology: No Samples Collected. Fluids Lost: 0 bbls Max Gas: 2226 Units to run to 1,930' MD. Rigged down E-line and attempted once again to regain circulation while working pipe. Rig up Schlumberger only get to 2300' MD. Rigged down E-line and rigged up a different truck with a smaller diameter line, but after multiple attempts Bit # 4.09.209.23 Size 3 Varel V613PDUX KCI/Polymer 6795' 12100' MWD Summary 95% Rig Activity: Saxon 169 Report For: 0.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 27 Customer: Well: Area: Location: Rig: Depth Condition 18-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) Avg Min % Chlorides 0 0Background 2 mg/l 32000 6795' 0 0 W orked pipe and attempted to rotate, with no luck. Rigged up E-line and attempted to run into the hole but could Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Finished rigging up Schlumberger and held a pre job safety meeting. Pressure Tested lines to 7,500 psi, pressured Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 32000 6795' 0 0 0 0Background Avg Min % Chlorides 0 Depth Condition 19-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 28 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 0.0 Date: Bit # 4.39.259.22 Size 3 Varel V613PDUX KCI/Polymer 6795' 12100' Geology: No Samples Collected. Fluids Lost: 0 bbls Max Gas: Units changed out long bails back to drilling bails, and Slip & cut drill line. Continuing to jar and work pipe free. continued working/jarring pipe. Rigged up slick line and ran in hole with 2" dummy gun drift; no luck. Rigged down slick line, 2495' 78' 100% Gas In Air=10,000 Units0Connection 4 RPM ECD (ppg) ml/30min 3.2 0 pH Tools API FL (max) Trip (max)(current) Average 0 Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 9.20 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 5303' 2428' 21 12098' WOB 0.00 78' 2506' 16 R. Pederson / S. Barber ShClyst 0.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 W aiting on Coil Tubing Avg to 29.7 (current) 6.75 0.557 in 12098' 0.0 pressured up string to 6,900 psi, and then bled back to 5,900 psi with no returns. Rigged down Schlumberger pump truck and 2 12098' 12098' 0' Max @ ft Current Minimum Depth Time: 0' 0 0' Gas Summary 0 0 C-5n 9 Set AtSize Cly TFABit Type Depth 2.559 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 31 L-80 281Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 0Maximum 0 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 0 10.75'' Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.555 MBT (ppb Eq) Hours 0 0 C-5n 0 Set AtSize Cly 0' 0 0' Gas Summary 12098' 12098' 0' Max @ ft Current Minimum Depth Time: in 0' 0.0 0 R/U Coil Tubing Avg to 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 R. Pederson / S. Barber ShClyst 0.0 Sst SPP(psi) Gallons/stroke 5303' 2428' 20 12098' WOB 0.00 78' 2506' 12 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.90 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Average 0 (max) Trip (max)(current) RPM ECD (ppg) ml/30min 3.5 0 pH Tools API FL 2495' 78' 100% Gas In Air=10,000 Units0Connection 4 Geology: No Samples Collected. Fluids Lost: 0 bbls Max Gas: 0 Units Bit # 4.19.209.20 Size 3 Varel V613PDUX KCI/Polymer 6795' 12100' MWD Summary 95% Rig Activity: Saxon 169 Report For: 0.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 29 Customer: Well: Area: Location: Rig: Depth Condition 20-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) Avg Min % Chlorides 0 0Background 0 mg/l 30500 6795' 0 0 Continued rig mainenance while waiting on coil tubing. Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Continued running hole with coil tubing, tested blow out preventer, and rigged up injector head. Run into the hole Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 30500 6795' 0 0 0 0Background Avg Min % Chlorides 0 Depth Condition 21-Jun-2015 23:59 Current Pump & Flow Data: Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 30 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 0.0 Date: Bit # 4.09.209.25 Size 3 Varel V613PDUX KCI/Polymer 6795' 12100' Geology: No Samples Collected. Fluids Lost: 0 bbls Max Gas: 0 Units 2495' 78' 100% Gas In Air=10,000 Units0Connection 4 RPM ECD (ppg) ml/30min 3.3 0 pH Tools API FL (max) Trip (max)(current) Average 0 Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.40 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 5303' 2428' 19 12098' WOB 0.00 78' 2506' 12 R. Pederson / S. Barber ShClyst 0.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 RIH with Coil Tubing Avg to 29.7 (current) 6.75 0.557 in 0' 0.0 with coil tubing to perforate at time of report. 0 12098' 12098' 0' Max @ ft Current Minimum Depth Time: 0' 0 0' Gas Summary 0 0 C-5n 0 Set AtSize Cly TFABit Type Depth 2.554 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jeremy Tiegs 0 L-80 0Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Eric Andrews . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 1986Maximum 0 90 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 276 10.75'' 352 145 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.057 MBT (ppb Eq) Hours 0 0 C-5n 17 Set AtSize Cly 0' 0 0' Gas Summary 7500' 7520' 20' Max @ ft Current Minimum Depth Time: in 7522' 0.0 hour 7,523' MD. Currently zero gas. Lithology is containing around 10% cement. 3 N/A Time Drilling @ 4 ft/hr Avg to 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A S. Hauck / D. Yessak ShClyst 0.0 Sst SPP(psi) Gallons/stroke 2428' 23 WOB 0.00 78' 2506' 14 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 10 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.30 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Average 0 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 3.9 0 pH Tools API FL 2495' 78' 100% Gas In Air=10,000 Units0Connection 4 Geology: 90% Siltstone; 10% Cement Fluids Lost: 0 bbls Max Gas: 17 Units Bit # 3.99.209.20 Size 3 Varel V613PDUX KCI/Polymer 6795' 7517' MWD Summary 95% Rig Activity: Saxon 169 Report For: 0.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 31 Customer: Well: Area: Location: Rig: Depth Condition 1-Jul-2015 23:59 Current Pump & Flow Data: 2085 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 3Background 0 mg/l 33000 6795' 0 0 Ran in hole to 7,499. Began time drilling at 1' pre hour to 7,505', then 2' pre hour to 7,517', and increased to 4' per Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Continued time drilling at 4 ft/hr to 7,534' MD. Rotated and slid to 7,881' MD and ran sweeps. Continued drilling Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 35000 6795' 0 0 0 170Background Avg Min % Chlorides 0 Depth Condition 2-Jul-2015 23:59 Current Pump & Flow Data: 2180 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 32 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 78.0 Date: Bit # 5.29.409.40 Size 3 Varel V613PDUX KCI/Polymer 6795' 8339' Geology: 80% Siltstone, 10% Claystone, 10% Coal Fluids Lost: 0 bbls Max Gas: 327 Units 2495' 78' 100% Gas In Air=10,000 Units227Connection 10 4 RPM ECD (ppg) ml/30min 4.0 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max)Trip (max)(current) Average 75 Mud Type Lst Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.10 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 2428' 21 WOB 0.00 78' 2506' 15 S. Hauck / D. Yessak ShClyst 10 120.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A N/A Drilling ahead Avg to7500' 29.7 (current) 6.75 0.557 in 8353' 60.0 ahead to 8,339' and pumped sweeps. Pulled back and did short trip to 7,479'. RIH and currently drilling ahead at 8,405' MD. 51 7520' 8390' 870' Max @ ft Current Minimum Depth Time: 7671' 2 7579' Gas Summary 0 0 C-5n 327 Set AtSize Cly TFABit Type Depth 2.353 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 351 145 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 4862 L-80 39596Maximum 271 80 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 71533 30 Maximum 195 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 12687 10.75'' 351 145 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 2.559 MBT (ppb Eq) Hours 0 0 C-5n 606 Set AtSize Cly 9104' 1 9109' Gas Summary 8390' 9455' 1065' Max @ ft Current Minimum Depth Time: in 9168' 0.0 with a bit depth of 8,000' MD 126 N/A POOH to Shoe Avg to7500' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A S. Hauck / D. Yessak ShClyst 116.0 Sst SPP(psi) Gallons/stroke 2428' 22 WOB 0.00 78' 2506' 19 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 10.10 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 70 Intermediate Casing Type Chromatograph (ppm) Average 568 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 3.4 0 pH Tools Directional, Gamma, Res, Mud Motor API FL 2495' 78' 100% Gas In Air=10,000 Units578Connection 15 Geology: 70% Sandstone, 30% Sand Fluids Lost: 0 bbls Max Gas: 606 Units Bit # 6.19.459.45 Size 3 Varel V613PDUX KCI/Polymer 6795' 9456' MWD Summary 95% Rig Activity: Saxon 169 Report For: 80.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 33 Customer: Well: Area: Location: Rig: Depth Condition 3-Jul-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 3Background 0 mg/l 30500 6795' 0 0 Continued drilling ahead 9,456' MD and pumped sweep. Began short trip to the casing shoe. Currently POOH Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' TOOH to casing shoe at 6,723' MD to change out motor on top drive and slip and cut drill line. TIH and began drilling Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 32000 6795' 0 0 0 65Background Avg Min % Chlorides 0 Depth Condition 4-Jul-2015 23:59 Current Pump & Flow Data: 2422 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 34 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 82.0 Date: Bit # 5.69.409.40 Size 3 Varel V613PDUX KCI/Polymer 6795' 9943' Geology: 60% Sandstone, 20% Coal, 10% Sand, 10% Tuff Fluids Lost: 0 bbls Max Gas: 1013 Units and background gas around 65 units. 2495' 78' 100% Gas In Air=10,000 Units578Connection 31 RPM ECD (ppg) ml/30min 3.4 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max)Trip (max)(current) Average 492 Mud Type Lst 60 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 10.00 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 2428' 18 WOB 0.00 78' 2506' 16 S. Hauck / D. Yessak ShClyst 20 125.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A N/A Drilling Ahead Avg to7500' 29.7 (current) 6.75 0.557 10 in 9822' 18.0 ahead to 9,891' and experienced tight spot. Pumped sweep and continued. Currently drilling ahead with bit depth of 10,028' MD 167 9455' 10021' 566' Max @ ft Current Minimum Depth Time: 9720' 19 9605' Gas Summary 0 0 C-5n 1013 Set AtSize Cly TFABit Type Depth 3.356 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 351 145 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 15924 L-80 114403 10 Maximum 6393 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 122867Maximum 7676 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 17316 10.75'' 331 137 Units* Casing Summary Lithology (%) C-2 6 0 Siltst 0 0 TFABit Type Depth 3.555 MBT (ppb Eq) Hours 0 0 C-5n 1091 Set AtSize Cly 10174' 10 10360' Gas Summary 10021' 10447' 426' Max @ ft Current Minimum Depth Time: in 10335' OFF a sweep. Began short trip and well was flowing and gas began rising to 646 units. Currently conducting a flow check with 9.9 ppg 187 N/A Conducting flow check Avg to7500' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A S. Hauck / D. Yessak ShClyst 30 125.0 Sst SPP(psi) Gallons/stroke 2428' 21 WOB 0.00 78' 2506' 16 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.60 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 70 Intermediate Casing Type Chromatograph (ppm) Average 646 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 3.1 0 pH Tools Directional, Gamma, Res, Mud Motor API FL mud wieght. 2495' 78' 100% Gas In Air=10,000 Units252Connection 29 Geology: 70% Sandstone, 30% Coal Fluids Lost: 0 bbls Max Gas: 1091 Units Bit # 7.39.859.85 Size 3 Varel V613PDUX KCI/Polymer 6795' 10447' MWD Summary 95% Rig Activity: Saxon 169 Report For: 68.0 Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 35 Customer: Well: Area: Location: Rig: Depth Condition 5-Jul-2015 23:59 Current Pump & Flow Data: 2281 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 35Background 5 mg/l 31500 6795' 0 0 Drilled ahead to 10,165' MD and pumped tandem sweep. Continued drilling ahead to 10,447' MD and pumped Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Weighed up mud to 10 ppg and well was still flowing. Decision was made to drill ahead to get out of coal. Made up Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 32500 6795' 0 0 5 0Background Avg Min % Chlorides 0 Depth Condition 6-Jul-2015 23:59 Current Pump & Flow Data: - Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 36 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Bit # 8.710.2510.25 Size 3 Varel V613PDUX KCI/Polymer 6795' 10447' Geology: 70% Sandstone, 30% Coal Fluids Lost: 0 bbls Max Gas: 651 Units changing out top drive. 2495' 78' 100% Gas In Air=10,000 Units-Connection 29 RPM ECD (ppg) ml/30min 2.8 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max)Trip (max)(current) Average 651 Mud Type Lst 70 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 9.80 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 2428' 25 WOB 0.00 78' 2506' 19 S. Hauck / D. Yessak ShClyst 30 - Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A N/A Change out Top Drive Avg to7500' 29.7 (current) 6.75 0.557 in - - a stand and top drive began leaking hydraulic fluid. Could not fix top drive so decision was made to trip to casing shoe. Currently 17 10447' 10447' 0' Max @ ft Current Minimum Depth Time: - 0 - Gas Summary 0 0 C-5n 651 Set AtSize Cly TFABit Type Depth 3.570 MBT (ppb Eq) Hours 6 0 Siltst 0 0 10.75'' - - Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 1685 L-80 0Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 11557Maximum 0 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 0 10.75'' 313 129 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 3.567 MBT (ppb Eq) Hours 0 0 C-5n 145 Set AtSize Cly - 0 - Gas Summary 10447' 10447' 0' Max @ ft Current Minimum Depth Time: in - - and continued to RIH to 8,650' MD. Pumped a sweep and circulated. Currently RIH with a bit depth of 8,840' MD. 10 N/A RIH Avg to7500' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A S. Hauck / D. Yessak ShClyst 30 - Sst SPP(psi) Gallons/stroke 2428' 20 WOB 0.00 78' 2506' 19 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.80 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 70 Intermediate Casing Type Chromatograph (ppm) Average 145 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 2.8 0 pH Tools Directional, Gamma, Res, Mud Motor API FL 2495' 78' 100% Gas In Air=10,000 Units-Connection 0 Geology: 70% Sandstone, 30% Coal Fluids Lost: 0 bbls Max Gas: 145 Units Bit # 8.410.1010.10 Size 3 Varel V613PDUX KCI/Polymer 6795' 10447' MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 37 Customer: Well: Area: Location: Rig: Depth Condition 7-Jul-2015 23:59 Current Pump & Flow Data: 2260 Max ROP ROP (ft/hr) Avg Min % Chlorides 0 3Background 0 mg/l 30500 6795' 0 0 Finished changing out the top drive. RIH till bit reached outside of the casing shoe. Rotated and checked the torque Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' RIH with bottoms up gas of 2527 units. Drilled ahead to 10,821' and pumped sweep. Currently drilling ahead at Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 30000 6795' 0 0 6 55Background Avg Min % Chlorides 0 Depth Condition 8-Jul-2015 23:59 Current Pump & Flow Data: 2448 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 38 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: 56.0 Date: Bit # 8.110.0010.00 Size 3 Varel V613PDUX KCI/Polymer 6795' 11055' Geology: 60% Siltstone, 20% Sandstone, 20% Coal Fluids Lost: 0 bbls Max Gas: 2529 Units 2495' 78' 100% Gas In Air=10,000 Units327Connection 19 RPM ECD (ppg) ml/30min 3.2 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max)Trip (max)(current) Average 2527 Mud Type Lst 20 Intermediate Casing Type Chromatograph (ppm) Comments Conductor 0 0 0 0 000 9.50 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 2428' 19 WOB 0.00 78' 2506' 16 R. Pederson / D. Yessak ShClyst 20 109.0 Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A N/A Drilling ahead Avg to7500' 29.7 (current) 6.75 0.557 in 10904' 52.0 11,170' with background gas of around 55 units. 167 10447' 11154' 707' Max @ ft Current Minimum Depth Time: 10898' 5 10921' Gas Summary 0 0 C-5n 708 Set AtSize Cly TFABit Type Depth 3.556 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 327 135 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 12886 L-80 72123Maximum 578 60 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Drilled ahead to 11,200' MD and TD'd. Pumped sweep and wiper tripped to casing shoe with no issues. Circulated Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 28500 6795' 0 0 4 0Background 0 Avg Min % Chlorides 0 Depth Condition 9-Jul-2015 23:59 Current Pump & Flow Data: - Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 39 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Bit # 8.010.0010.00 Size 3 Varel V613PDUX KCI/Polymer 6795' 11200' Geology: 50% Sandstone, 50% Coal Fluids Lost: 0 bbls Max Gas: 2801 Units 2495' 78' 100% Gas In Air=10,000 Units-Connection 16 RPM ECD (ppg) ml/30min 0 3.1 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max)Trip (max)(current) Average 2801 Mud Type Lst 50 Intermediate Casing Type Chromatograph (ppm) 0 Comments Conductor 0 0 0 0 000 10.00 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 4405' 2428' 20 11200' WOB 0.00 78' 2506' 16 R. Pederson / D. Yessak ShClyst 50 - Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A N/A TOOH Avg to7500' 29.7 (current) 6.75 0.557 in 11158' - until the wellbore cleaned up and POOH to the shoe with no issues. POOH to BHA at time of report. 119 11154' 11200' 46' Max @ ft Current Minimum Depth Time: - 8 11188' Gas Summary 0 0 C-5n 442 Set AtSize Cly TFABit Type Depth 3.855 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' - - Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 12845 L-80 48670Maximum 715 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 12560Maximum 0 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 183 10.75'' - - Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 3.556 MBT (ppb Eq) Hours 0 0 C-5n 121 11200' Set AtSize Cly - 0 - Gas Summary 11200' 11200' 0' Max @ ft Current Minimum Depth Time: in - - to 6,751' MD. Slip and cut drill line and began rig service and replacing top drive motor. Currently changing out motor at time of 2 N/A Slip and cut; replace motor Avg to7500' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A R. Pederson / D. Yessak ShClyst 50 - Sst SPP(psi) Gallons/stroke 4405' 2428' 19 11200' WOB 0.00 78' 2506' 15 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 3.50 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 50 Intermediate Casing Type Chromatograph (ppm) 0 Average 121 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 0 3.0 0 pH Tools Directional, Gamma, Res, Mud Motor API FL report. 2495' 78' 100% Gas In Air=10,000 Units-Connection 4 Geology: 50% Sandstone, 50% Coal Fluids Lost: 0 bbls Max Gas: 121 Units Bit # 8.110.0510.05 Size 3 Varel V613PDUX KCI/Polymer 6795' 11200' MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 40 Customer: Well: Area: Location: Rig: Depth Condition 10-Jul-2015 23:59 Current Pump & Flow Data: - Max ROP ROP (ft/hr) 0 Avg Min % Chlorides 0 0Background 0 mg/l 29500 6795' 0 0 Finished POOH and L/D BHA. Tested BOP and picked up Mad Pass BHA and ran in the hole with it. RIH Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' Finshed replacing the top drive motor. Continued to RIH to 8,961' fill pipe and continued to 11,145' MD and washed Density (ppg) out (sec/qt) Viscosity Cor Solids 629' mg/l 29000 6795' 0 0 11 2Background 0 Avg Min % Chlorides 0 Depth Condition 11-Jul-2015 23:59 Current Pump & Flow Data: 2242 Max ROP ROP (ft/hr) 2.94 @ Mud Data Morning Report Report # 41 Customer: Well: Area: Location: Rig: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Bit # 8.010.0010.00 Size 3 Varel V613PDUX KCI/Polymer 6795' 11200' Geology: 50% Sandstone, 50% Coal Fluids Lost: 0 bbls Max Gas: 2470 Units 2495' 78' 100% Gas In Air=10,000 Units-Connection 46 RPM ECD (ppg) ml/30min 0 3.2 0 pH Tools Directional, Gamma, Res, Mud Motor API FL (max)Trip (max)(current) Average 2470 Mud Type Lst 50 Intermediate Casing Type Chromatograph (ppm) 0 Comments Conductor 0 0 0 0 000 9.80 C-3 00 Cement Depth in / out PV 24 hr Max 45.5 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 4405' 2428' 19 11200' WOB 0.00 78' 2506' 14 R. Pederson / D. Yessak ShClyst 50 - Sst SPP(psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A N/A Mad Pass Avg to7500' 29.7 (current) 6.75 0.557 in - - last stand down. Began mad passing up the hole. Currently mad passing at 9,250' MD. Background gas has been around 15 units. 55 11200' 11200' 0' Max @ ft Current Minimum Depth Time: - 0 - Gas Summary 0 0 C-5n 2470 11200' Set AtSize Cly TFABit Type Depth 3.352 MBT (ppb Eq) Hours 0 0 Siltst 0 0 10.75'' 318 131 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 48390 L-80 226327Maximum 0 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson . . * 24 hr Recap: 0 Grade L-80 907-283-1309Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 9783Maximum 0 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 453 10.75'' - - Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 3.555 MBT (ppb Eq) Hours 0 0 C-5n 101 11200' Set AtSize Cly - 0 - Gas Summary 11200' 11200' 0' Max @ ft Current Minimum Depth Time: in - - down pipe. Currently laying down BHA. 5 N/A L/D BHA Avg to7500' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A R. Pederson / D. Yessak ShClyst 50 - Sst SPP(psi) Gallons/stroke 4405' 2428' 22 11200' WOB 0.00 78' 2506' 14 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.90 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 50 Intermediate Casing Type Chromatograph (ppm) 0 Average 101 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 0 3.0 0 pH Tools Directional, Gamma, Res, Mud Motor API FL 2495' 78' 100% Gas In Air=10,000 Units-Connection 0 Geology: 50% Sandstone, 50% Coal Fluids Lost: 0 bbls Max Gas: 101 Units Bit # 7.810.0010.00 Size 3 Varel V613PDUX KCI/Polymer 6795' 11200' MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.94 @ Mud Data Morning Report Report # 42 Customer: Well: Area: Location: Rig: Depth Condition 12-Jul-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 0 Avg Min % Chlorides 0 0Background 11 mg/l 31500 6795' 0 0 Continued MAD passing to 7,600' MD. TOOH to shoe and flow checked well. Pumped dry job and TOOH laying Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' . . * 24 hr Recap: 0 Grade L-80 907-283-1385Unit Phone: 0 Jacob Robertson 01HDBS QHC1GRC Mill 13.5 0.739 6794' 16.00'' 7.63'' Surface Casing L-80 24901Maximum 0 Report By:Logging Engineers:Eric Andrews / Jacob Robertson 296 10.75'' 201 83 Units* Casing Summary Lithology (%) C-2 0 0 Siltst 0 0 TFABit Type Depth 3.556 MBT (ppb Eq) Hours 0 0 C-5n 224 11200' Set AtSize Cly - 0 - Gas Summary 11200' 11200' 0' Max @ ft Current Minimum Depth Time: in - - drill pipe to casing shoe and circulated bottoms up. RIH to 9,918' MD and circulated B/U. Continued to RIH to 11,171' MD and 3 N/A Circulating Avg to7500' 29.7 (current) 6.75 0.557 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0902378615 N/A R. Pederson / D. Yessak ShClyst 50 - Sst SPP(psi) Gallons/stroke 4405' 2428' 22 11200' WOB 0.00 78' 2506' 14 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 0.00 Depth in / out PV 24 hr Max 45.5 Weight Sd YP 0 9.10 C-3 00 Cement 0 0 0 0 00 Comments Conductor Mud Type Lst 50 Intermediate Casing Type Chromatograph (ppm) 0 Average 224 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 0 3.1 0 pH Tools Directional, Gamma, Res, Mud Motor API FL rigged up cement head and ran to 11,198' MD. Circulated B/U. Circulating at time of report. 2495' 78' 100% Gas In Air=10,000 Units-Connection 0 Geology: 50% Sandstone, 50% Coal Fluids Lost: 0 bbls Max Gas: 224 Units Bit # 8.010.0010.00 Size 3 Varel V613PDUX KCI/Polymer 6795' 11200' MWD Summary 95% Rig Activity: Saxon 169 Report For: - Date: Blossom #1 Hilcorp Alaska LLC Kenai Peninsula Ninilchik Field Job No.: Daily Charges: Total Charges: 2.44 @ Mud Data Morning Report Report # 43 Customer: Well: Area: Location: Rig: Depth Condition 13-Jul-2015 23:59 Current Pump & Flow Data: 950 Max ROP ROP (ft/hr) 0 Avg Min % Chlorides 0 0Background 11 mg/l 30000 6795' 0 0 Finished L/D BHA. M/U casing liner and began RIH with 4.5" production liner. M/U hanger and continued RIH with Density (ppg) out (sec/qt) Viscosity Cor Solids 629'2 HDBS MM 65 PDC 9.875 0.778 0.00 2506' 16 July, 2015 Ninilchik Unit Blossom Rig: Blossom #1 50-133-20648-00-00 50-133-20648-00-00 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Rig: Blossom #1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Ninilchik Unit Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Blossom #1 usft usft 0.00 0.00 2,258,238.57 231,709.77 215.20Wellhead Elevation:0.00 usft0.00 60° 10' 23.684 N 151° 28' 24.180 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Rig: Blossom #1 Model NameMagnetics BGGM2014 5/5/2015 16.46 73.18 55,197 Phase:Version: Audit Notes: Design Blossom #1 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:7,470.82 332.860.000.0018.00 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 7/16/2015 Survey Date MWD+SC+sag Fixed:v2:standard dec & axial correction + sag137.96 2,423.71 Blossom #1 PB1 MWD 1 (Blossom #1PB 05/01/2015 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag2,488.40 6,748.34 Blossom #1 PB1 MWD 2 (Blossom #1PB 06/29/2015 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag6,827.19 7,470.82 Blossom #1 PB1 MWD 3 (Blossom #1PB 06/29/2015 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag7,504.07 11,166.86 Blossom #1 MWD 4 (Rig: Blossom #1)06/29/2015 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18.00 0.00 0.00 18.00 0.00 0.00-215.20 2,258,238.57 231,709.77 0.00 0.00 UNDEFINED 137.96 0.47 356.49 137.96 0.49 -0.03-95.24 2,258,239.06 231,709.75 0.39 0.45 MWD+SC+sag (1) 193.23 0.62 356.49 193.23 1.02 -0.06-39.97 2,258,239.59 231,709.73 0.27 0.93 MWD+SC+sag (1) 260.25 3.65 331.63 260.19 3.26 -1.1026.99 2,258,241.85 231,708.74 4.62 3.40 MWD+SC+sag (1) 322.23 6.22 329.91 321.94 7.90 -3.7288.74 2,258,246.55 231,706.23 4.15 8.72 MWD+SC+sag (1) 383.82 9.01 330.69 382.98 14.99 -7.75149.78 2,258,253.73 231,702.35 4.53 16.88 MWD+SC+sag (1) 444.21 11.76 329.46 442.37 24.42 -13.20209.17 2,258,263.27 231,697.12 4.57 27.75 MWD+SC+sag (1) 504.64 14.32 329.44 501.24 36.16 -20.13268.04 2,258,275.17 231,690.45 4.24 41.36 MWD+SC+sag (1) 568.32 17.28 330.08 562.51 51.14 -28.85329.31 2,258,290.34 231,682.07 4.66 58.67 MWD+SC+sag (1) 629.58 19.73 329.56 620.60 67.94 -38.63387.40 2,258,307.36 231,672.67 4.01 78.08 MWD+SC+sag (1) 691.16 22.53 328.92 678.03 87.01 -49.99444.83 2,258,326.67 231,661.74 4.56 100.23 MWD+SC+sag (1) 7/16/2015 6:42:37PM COMPASS 5000.1 Build 73 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Rig: Blossom #1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 753.82 25.09 329.46 735.35 108.74 -62.94502.15 2,258,348.68 231,649.27 4.10 125.48 MWD+SC+sag (1) 814.96 27.38 329.23 790.19 131.99 -76.72556.99 2,258,372.23 231,636.02 3.75 152.45 MWD+SC+sag (1) 877.06 30.23 329.97 844.60 157.80 -91.85611.40 2,258,398.37 231,621.46 4.63 182.32 MWD+SC+sag (1) 938.85 33.44 330.69 897.09 186.12 -107.97663.89 2,258,427.05 231,605.98 5.23 214.88 MWD+SC+sag (1) 1,000.99 36.39 330.78 948.04 217.14 -125.36714.84 2,258,458.45 231,589.29 4.75 250.42 MWD+SC+sag (1) 1,063.70 39.18 331.38 997.59 250.77 -143.93764.39 2,258,492.48 231,571.47 4.49 288.82 MWD+SC+sag (1) 1,124.86 42.16 329.96 1,043.98 285.51 -163.47810.78 2,258,527.65 231,552.72 5.10 328.64 MWD+SC+sag (1) 1,186.33 45.05 329.56 1,088.49 322.13 -184.82855.29 2,258,564.73 231,532.19 4.72 370.97 MWD+SC+sag (1) 1,249.03 48.08 330.44 1,131.59 361.56 -207.57898.39 2,258,604.66 231,510.32 4.94 416.43 MWD+SC+sag (1) 1,311.55 50.29 329.26 1,172.45 402.46 -231.34939.25 2,258,646.09 231,487.47 3.81 463.68 MWD+SC+sag (1) 1,373.34 52.53 328.92 1,210.99 443.90 -256.15977.79 2,258,688.06 231,463.59 3.65 511.87 MWD+SC+sag (1) 1,434.45 54.15 329.45 1,247.48 486.00 -281.261,014.28 2,258,730.71 231,439.43 2.74 560.79 MWD+SC+sag (1) 1,495.98 57.11 329.38 1,282.21 529.71 -307.101,049.01 2,258,774.99 231,414.57 4.81 611.48 MWD+SC+sag (1) 1,558.19 61.14 329.70 1,314.13 575.73 -334.161,080.93 2,258,821.60 231,388.54 6.49 664.77 MWD+SC+sag (1) 1,620.81 63.35 329.98 1,343.29 623.64 -362.001,110.09 2,258,870.12 231,361.78 3.55 720.11 MWD+SC+sag (1) 1,681.65 67.29 330.96 1,368.68 671.74 -389.231,135.48 2,258,918.81 231,335.63 6.64 775.33 MWD+SC+sag (1) 1,743.66 71.15 331.97 1,390.68 722.66 -416.921,157.48 2,258,970.34 231,309.09 6.41 833.28 MWD+SC+sag (1) 1,805.85 74.49 332.18 1,409.05 775.15 -444.741,175.85 2,259,023.44 231,282.44 5.38 892.68 MWD+SC+sag (1) 1,868.60 75.97 331.80 1,425.04 828.72 -473.231,191.84 2,259,077.63 231,255.15 2.43 953.35 MWD+SC+sag (1) 1,930.01 77.16 331.61 1,439.31 881.31 -501.541,206.11 2,259,130.84 231,228.02 1.96 1,013.06 MWD+SC+sag (1) 1,990.97 76.62 332.10 1,453.14 933.66 -529.551,219.94 2,259,183.80 231,201.19 1.18 1,072.42 MWD+SC+sag (1) 2,054.34 74.47 332.56 1,468.96 988.00 -558.051,235.76 2,259,238.76 231,173.91 3.46 1,133.78 MWD+SC+sag (1) 2,116.65 73.19 332.71 1,486.31 1,041.15 -585.551,253.11 2,259,292.51 231,147.60 2.07 1,193.62 MWD+SC+sag (1) 2,178.22 73.53 330.07 1,503.94 1,092.93 -613.801,270.74 2,259,344.91 231,120.52 4.15 1,252.59 MWD+SC+sag (1) 2,240.18 73.88 329.53 1,521.33 1,144.33 -643.711,288.13 2,259,396.96 231,091.76 1.01 1,311.98 MWD+SC+sag (1) 2,301.32 75.98 329.08 1,537.22 1,195.10 -673.851,304.02 2,259,448.38 231,062.76 3.51 1,370.90 MWD+SC+sag (1) 2,363.14 76.12 329.37 1,552.13 1,246.64 -704.551,318.93 2,259,500.60 231,033.22 0.51 1,430.77 MWD+SC+sag (1) 2,423.71 74.98 329.94 1,567.24 1,297.26 -734.181,334.04 2,259,551.86 231,004.73 2.09 1,489.33 MWD+SC+sag (1) 2,488.40 75.15 330.52 1,583.91 1,351.52 -765.221,350.71 2,259,606.80 230,974.91 0.91 1,551.77 MWD+SC+sag (2) 2,495.00 75.03 330.58 1,585.61 1,357.07 -768.351,352.41 2,259,612.42 230,971.90 1.95 1,558.14 MWD+SC+sag (2) 10 3/4" 2,550.18 74.07 331.07 1,600.31 1,403.51 -794.281,367.11 2,259,659.42 230,947.01 1.95 1,611.30 MWD+SC+sag (2) 2,610.36 73.37 330.84 1,617.18 1,454.01 -822.321,383.98 2,259,710.54 230,920.10 1.22 1,669.03 MWD+SC+sag (2) 2,674.52 72.47 331.45 1,636.02 1,507.72 -851.921,402.82 2,259,764.90 230,891.71 1.67 1,730.33 MWD+SC+sag (2) 2,736.22 72.98 331.39 1,654.35 1,559.46 -880.111,421.15 2,259,817.25 230,864.69 0.83 1,789.23 MWD+SC+sag (2) 2,795.57 73.54 330.36 1,671.44 1,609.11 -907.771,438.24 2,259,867.50 230,838.14 1.91 1,846.03 MWD+SC+sag (2) 2,857.65 72.74 331.45 1,689.45 1,661.02 -936.661,456.25 2,259,920.04 230,810.42 2.12 1,905.41 MWD+SC+sag (2) 2,919.60 75.99 329.44 1,706.14 1,712.90 -966.091,472.94 2,259,972.57 230,782.15 6.11 1,965.00 MWD+SC+sag (2) 2,981.31 76.37 329.17 1,720.88 1,764.43 -996.681,487.68 2,260,024.76 230,752.72 0.75 2,024.81 MWD+SC+sag (2) 3,043.14 77.20 329.36 1,735.02 1,816.17 -1,027.441,501.82 2,260,077.17 230,723.12 1.38 2,084.88 MWD+SC+sag (2) 7/16/2015 6:42:37PM COMPASS 5000.1 Build 73 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Rig: Blossom #1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,105.40 76.17 329.33 1,749.36 1,868.29 -1,058.331,516.16 2,260,129.97 230,693.40 1.66 2,145.35 MWD+SC+sag (2) 3,168.37 76.94 329.55 1,764.00 1,921.02 -1,089.471,530.80 2,260,183.39 230,663.45 1.27 2,206.49 MWD+SC+sag (2) 3,229.29 76.88 329.78 1,777.79 1,972.24 -1,119.441,544.59 2,260,235.25 230,634.63 0.38 2,265.73 MWD+SC+sag (2) 3,291.55 77.19 329.41 1,791.76 2,024.56 -1,150.141,558.56 2,260,288.25 230,605.10 0.76 2,326.31 MWD+SC+sag (2) 3,353.80 77.63 329.46 1,805.33 2,076.88 -1,181.041,572.13 2,260,341.24 230,575.38 0.71 2,386.95 MWD+SC+sag (2) 3,415.63 76.10 329.75 1,819.38 2,128.81 -1,211.501,586.18 2,260,393.84 230,546.08 2.52 2,447.06 MWD+SC+sag (2) 3,478.20 76.23 329.47 1,834.34 2,181.22 -1,242.241,601.14 2,260,446.92 230,516.52 0.48 2,507.72 MWD+SC+sag (2) 3,537.60 76.00 329.59 1,848.60 2,230.92 -1,271.481,615.40 2,260,497.26 230,488.40 0.43 2,565.29 MWD+SC+sag (2) 3,601.71 75.41 329.04 1,864.43 2,284.35 -1,303.181,631.23 2,260,551.38 230,457.90 1.24 2,627.29 MWD+SC+sag (2) 3,663.09 76.25 328.34 1,879.45 2,335.19 -1,334.111,646.25 2,260,602.90 230,428.11 1.76 2,686.65 MWD+SC+sag (2) 3,725.67 76.43 329.07 1,894.23 2,387.15 -1,365.691,661.03 2,260,655.55 230,397.69 1.17 2,747.30 MWD+SC+sag (2) 3,786.41 77.36 329.38 1,908.00 2,437.98 -1,395.961,674.80 2,260,707.04 230,368.57 1.61 2,806.33 MWD+SC+sag (2) 3,849.33 77.38 330.01 1,921.76 2,490.99 -1,426.941,688.56 2,260,760.72 230,338.78 0.98 2,867.64 MWD+SC+sag (2) 3,911.09 76.57 329.17 1,935.68 2,542.88 -1,457.401,702.48 2,260,813.28 230,309.49 1.86 2,927.71 MWD+SC+sag (2) 3,973.03 77.19 330.13 1,949.74 2,594.93 -1,487.881,716.54 2,260,866.00 230,280.18 1.81 2,987.94 MWD+SC+sag (2) 4,035.23 77.49 331.19 1,963.37 2,647.84 -1,517.621,730.17 2,260,919.56 230,251.63 1.73 3,048.58 MWD+SC+sag (2) 4,097.74 75.41 331.04 1,978.02 2,701.04 -1,546.971,744.82 2,260,973.40 230,223.47 3.34 3,109.32 MWD+SC+sag (2) 4,159.36 75.98 330.76 1,993.24 2,753.22 -1,576.011,760.04 2,261,026.21 230,195.60 1.02 3,168.99 MWD+SC+sag (2) 4,221.78 76.61 330.86 2,008.03 2,806.16 -1,605.581,774.83 2,261,079.80 230,167.22 1.02 3,229.60 MWD+SC+sag (2) 4,283.52 76.43 330.57 2,022.42 2,858.52 -1,634.951,789.22 2,261,132.80 230,139.02 0.54 3,289.59 MWD+SC+sag (2) 4,345.49 76.44 329.74 2,036.96 2,910.77 -1,664.931,803.76 2,261,185.71 230,110.22 1.30 3,349.77 MWD+SC+sag (2) 4,407.48 75.84 330.18 2,051.81 2,962.87 -1,695.061,818.61 2,261,238.47 230,081.26 1.19 3,409.87 MWD+SC+sag (2) 4,468.53 75.76 330.09 2,066.79 3,014.20 -1,724.531,833.59 2,261,290.44 230,052.94 0.19 3,468.99 MWD+SC+sag (2) 4,530.89 76.66 330.31 2,081.65 3,066.75 -1,754.631,848.45 2,261,343.65 230,024.03 1.48 3,529.49 MWD+SC+sag (2) 4,592.56 76.88 329.91 2,095.76 3,118.80 -1,784.541,862.56 2,261,396.35 229,995.28 0.73 3,589.45 MWD+SC+sag (2) 4,654.67 76.51 330.30 2,110.06 3,171.20 -1,814.671,876.86 2,261,449.41 229,966.33 0.85 3,649.83 MWD+SC+sag (2) 4,716.73 77.58 329.62 2,123.97 3,223.56 -1,844.951,890.77 2,261,502.42 229,937.23 2.03 3,710.23 MWD+SC+sag (2) 4,779.45 77.45 330.15 2,137.53 3,276.53 -1,875.671,904.33 2,261,556.07 229,907.69 0.85 3,771.38 MWD+SC+sag (2) 4,840.09 76.57 330.45 2,151.16 3,327.85 -1,904.951,917.96 2,261,608.03 229,879.57 1.53 3,830.41 MWD+SC+sag (2) 4,902.91 77.26 329.78 2,165.38 3,380.90 -1,935.441,932.18 2,261,661.75 229,850.27 1.51 3,891.53 MWD+SC+sag (2) 4,964.88 77.18 329.57 2,179.09 3,433.07 -1,965.951,945.89 2,261,714.58 229,820.93 0.35 3,951.87 MWD+SC+sag (2) 5,026.85 76.75 329.82 2,193.07 3,485.19 -1,996.411,959.87 2,261,767.37 229,791.64 0.80 4,012.15 MWD+SC+sag (2) 5,089.13 76.42 329.51 2,207.52 3,537.48 -2,027.011,974.32 2,261,820.32 229,762.22 0.72 4,072.64 MWD+SC+sag (2) 5,150.87 74.14 331.37 2,223.21 3,589.41 -2,056.471,990.01 2,261,872.90 229,733.92 4.70 4,132.29 MWD+SC+sag (2) 5,211.25 72.34 332.56 2,240.62 3,640.44 -2,083.642,007.42 2,261,924.52 229,707.89 3.53 4,190.09 MWD+SC+sag (2) 5,273.84 70.00 333.06 2,260.82 3,693.13 -2,110.712,027.62 2,261,977.80 229,682.01 3.81 4,249.33 MWD+SC+sag (2) 5,336.37 66.55 333.53 2,283.96 3,745.01 -2,136.822,050.76 2,262,030.25 229,657.07 5.56 4,307.41 MWD+SC+sag (2) 5,397.51 64.22 333.93 2,309.42 3,794.85 -2,161.422,076.22 2,262,080.62 229,633.59 3.86 4,362.98 MWD+SC+sag (2) 5,459.54 60.93 334.98 2,337.99 3,844.51 -2,185.162,104.79 2,262,130.81 229,610.95 5.51 4,418.01 MWD+SC+sag (2) 5,521.73 58.01 335.98 2,369.58 3,893.24 -2,207.402,136.38 2,262,180.02 229,589.81 4.90 4,471.52 MWD+SC+sag (2) 7/16/2015 6:42:37PM COMPASS 5000.1 Build 73 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Rig: Blossom #1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,583.84 55.06 336.28 2,403.82 3,940.62 -2,228.372,170.62 2,262,227.85 229,569.91 4.77 4,523.24 MWD+SC+sag (2) 5,646.10 51.99 335.76 2,440.83 3,986.36 -2,248.712,207.63 2,262,274.03 229,550.59 4.98 4,573.22 MWD+SC+sag (2) 5,707.72 49.10 335.36 2,479.99 4,029.67 -2,268.392,246.79 2,262,317.77 229,531.89 4.72 4,620.74 MWD+SC+sag (2) 5,769.13 46.80 335.29 2,521.11 4,071.10 -2,287.422,287.91 2,262,359.62 229,513.78 3.75 4,666.30 MWD+SC+sag (2) 5,832.11 44.04 336.19 2,565.32 4,111.99 -2,305.862,332.12 2,262,400.90 229,496.26 4.50 4,711.09 MWD+SC+sag (2) 5,893.66 41.60 336.98 2,610.46 4,150.38 -2,322.492,377.26 2,262,439.65 229,480.49 4.06 4,752.84 MWD+SC+sag (2) 5,954.93 38.68 336.99 2,657.29 4,186.73 -2,337.932,424.09 2,262,476.33 229,465.87 4.77 4,792.23 MWD+SC+sag (2) 6,016.03 36.18 336.04 2,705.81 4,220.79 -2,352.722,472.61 2,262,510.72 229,451.84 4.20 4,829.29 MWD+SC+sag (2) 6,078.10 34.39 334.81 2,756.48 4,253.39 -2,367.622,523.28 2,262,543.65 229,437.67 3.10 4,865.10 MWD+SC+sag (2) 6,140.90 31.27 336.00 2,809.24 4,284.34 -2,381.802,576.04 2,262,574.90 229,424.18 5.07 4,899.11 MWD+SC+sag (2) 6,202.47 28.79 336.59 2,862.54 4,312.55 -2,394.192,629.34 2,262,603.38 229,412.42 4.06 4,929.86 MWD+SC+sag (2) 6,264.19 25.13 336.12 2,917.54 4,338.18 -2,405.412,684.34 2,262,629.25 229,401.78 5.94 4,957.79 MWD+SC+sag (2) 6,327.13 21.92 336.33 2,975.24 4,361.17 -2,415.542,742.04 2,262,652.46 229,392.17 5.10 4,982.86 MWD+SC+sag (2) 6,388.54 19.62 335.06 3,032.66 4,381.02 -2,424.492,799.46 2,262,672.50 229,383.66 3.82 5,004.61 MWD+SC+sag (2) 6,451.05 19.95 335.28 3,091.48 4,400.22 -2,433.372,858.28 2,262,691.90 229,375.21 0.54 5,025.75 MWD+SC+sag (2) 6,513.77 19.66 335.22 3,150.49 4,419.52 -2,442.272,917.29 2,262,711.39 229,366.75 0.46 5,046.99 MWD+SC+sag (2) 6,576.51 19.58 335.75 3,209.59 4,438.68 -2,451.012,976.39 2,262,730.75 229,358.43 0.31 5,068.03 MWD+SC+sag (2) 6,638.20 19.51 335.77 3,267.72 4,457.50 -2,459.483,034.52 2,262,749.75 229,350.38 0.11 5,088.64 MWD+SC+sag (2) 6,700.75 19.46 336.00 3,326.69 4,476.55 -2,468.013,093.49 2,262,768.98 229,342.29 0.15 5,109.48 MWD+SC+sag (2) 6,748.34 19.33 336.25 3,371.58 4,491.00 -2,474.413,138.38 2,262,783.57 229,336.21 0.32 5,125.25 MWD+SC+sag (2) 6,785.00 19.34 336.86 3,406.17 4,502.13 -2,479.233,172.97 2,262,794.81 229,331.63 0.55 5,137.37 MWD+SC+sag (3) 7 5/8" 6,827.19 19.35 337.57 3,445.98 4,515.02 -2,484.653,212.78 2,262,807.81 229,326.51 0.55 5,151.30 MWD+SC+sag (3) 6,890.71 20.22 337.97 3,505.75 4,534.92 -2,492.783,272.55 2,262,827.89 229,318.83 1.39 5,172.72 MWD+SC+sag (3) 6,957.84 20.64 339.17 3,568.66 4,556.73 -2,501.343,335.46 2,262,849.89 229,310.76 0.88 5,196.04 MWD+SC+sag (3) 7,019.51 19.74 339.02 3,626.54 4,576.62 -2,508.933,393.34 2,262,869.94 229,303.61 1.46 5,217.20 MWD+SC+sag (3) 7,085.81 20.23 339.14 3,688.85 4,597.78 -2,517.023,455.65 2,262,891.28 229,295.99 0.74 5,239.72 MWD+SC+sag (3) 7,147.01 19.20 339.46 3,746.46 4,617.09 -2,524.323,513.26 2,262,910.75 229,289.12 1.69 5,260.24 MWD+SC+sag (3) 7,214.06 19.98 339.92 3,809.63 4,638.18 -2,532.123,576.43 2,262,932.00 229,281.80 1.19 5,282.56 MWD+SC+sag (3) 7,276.39 18.61 339.54 3,868.45 4,657.50 -2,539.253,635.25 2,262,951.47 229,275.10 2.21 5,303.00 MWD+SC+sag (3) 7,342.39 19.06 339.77 3,930.92 4,677.48 -2,546.663,697.72 2,262,971.61 229,268.14 0.69 5,324.16 MWD+SC+sag (3) 7,404.18 19.55 340.25 3,989.23 4,696.67 -2,553.643,756.03 2,262,990.96 229,261.58 0.83 5,344.43 MWD+SC+sag (3) 7,470.82 18.38 336.39 4,052.26 4,716.80 -2,561.623,819.06 2,263,011.25 229,254.06 2.57 5,365.98 MWD+SC+sag (3) 7,504.07 17.41 336.55 4,083.90 4,726.16 -2,565.703,850.70 2,263,020.71 229,250.19 2.92 5,376.17 MWD+SC+sag (4) 7,567.02 15.59 338.95 4,144.26 4,742.70 -2,572.493,911.06 2,263,037.39 229,243.77 3.09 5,393.98 MWD+SC+sag (4) 7,627.74 14.73 341.34 4,202.86 4,757.63 -2,577.893,969.66 2,263,052.44 229,238.71 1.75 5,409.73 MWD+SC+sag (4) 7,689.02 14.84 341.73 4,262.11 4,772.46 -2,582.844,028.91 2,263,067.38 229,234.09 0.24 5,425.19 MWD+SC+sag (4) 7,751.58 15.05 342.39 4,322.56 4,787.81 -2,587.814,089.36 2,263,082.83 229,229.46 0.43 5,441.12 MWD+SC+sag (4) 7,805.00 15.17 342.56 4,374.13 4,801.09 -2,592.004,140.93 2,263,096.20 229,225.57 0.24 5,454.85 MWD+SC+sag (4) Top of Fish 7,813.51 15.19 342.59 4,382.34 4,803.22 -2,592.674,149.14 2,263,098.34 229,224.95 0.24 5,457.04 MWD+SC+sag (4) 7/16/2015 6:42:37PM COMPASS 5000.1 Build 73 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Rig: Blossom #1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 7,876.12 15.35 338.83 4,442.74 4,818.77 -2,598.124,209.54 2,263,114.01 229,219.85 1.60 5,473.37 MWD+SC+sag (4) 7,938.77 15.22 338.76 4,503.18 4,834.17 -2,604.094,269.98 2,263,129.54 229,214.22 0.21 5,489.80 MWD+SC+sag (4) 7,999.47 15.35 339.74 4,561.73 4,849.13 -2,609.764,328.53 2,263,144.63 229,208.89 0.48 5,505.70 MWD+SC+sag (4) 8,061.72 16.04 337.06 4,621.66 4,864.78 -2,615.964,388.46 2,263,160.41 229,203.03 1.61 5,522.46 MWD+SC+sag (4) 8,123.77 15.81 338.01 4,681.33 4,880.51 -2,622.474,448.13 2,263,176.28 229,196.88 0.56 5,539.43 MWD+SC+sag (4) 8,185.66 16.58 335.67 4,740.76 4,896.38 -2,629.274,507.56 2,263,192.30 229,190.44 1.63 5,556.64 MWD+SC+sag (4) 8,247.54 16.23 336.73 4,800.12 4,912.37 -2,636.324,566.92 2,263,208.44 229,183.74 0.74 5,574.09 MWD+SC+sag (4) 8,308.15 17.42 335.71 4,858.14 4,928.42 -2,643.404,624.94 2,263,224.64 229,177.02 2.02 5,591.60 MWD+SC+sag (4) 8,369.40 18.26 335.57 4,916.44 4,945.51 -2,651.144,683.24 2,263,241.90 229,169.67 1.37 5,610.34 MWD+SC+sag (4) 8,430.50 18.15 336.20 4,974.49 4,962.93 -2,658.944,741.29 2,263,259.50 229,162.26 0.37 5,629.41 MWD+SC+sag (4) 8,495.41 18.34 336.04 5,036.13 4,981.52 -2,667.164,802.93 2,263,278.26 229,154.45 0.30 5,649.69 MWD+SC+sag (4) 8,555.67 19.35 336.87 5,093.16 4,999.36 -2,674.944,859.96 2,263,296.27 229,147.08 1.73 5,669.12 MWD+SC+sag (4) 8,616.67 19.51 337.27 5,150.69 5,018.05 -2,682.844,917.49 2,263,315.13 229,139.59 0.34 5,689.36 MWD+SC+sag (4) 8,677.65 19.55 336.85 5,208.16 5,036.82 -2,690.794,974.96 2,263,334.08 229,132.07 0.24 5,709.69 MWD+SC+sag (4) 8,741.33 19.01 336.53 5,268.27 5,056.13 -2,699.115,035.07 2,263,353.57 229,124.18 0.86 5,730.67 MWD+SC+sag (4) 8,806.00 19.99 336.33 5,329.23 5,075.92 -2,707.745,096.03 2,263,373.54 229,115.99 1.52 5,752.21 MWD+SC+sag (4) 8,867.55 20.71 337.31 5,386.94 5,095.60 -2,716.165,153.74 2,263,393.40 229,108.01 1.29 5,773.56 MWD+SC+sag (4) 8,928.11 20.47 337.59 5,443.63 5,115.26 -2,724.335,210.43 2,263,413.24 229,100.28 0.43 5,794.79 MWD+SC+sag (4) 8,990.34 20.67 337.54 5,501.89 5,135.47 -2,732.675,268.69 2,263,433.64 229,092.39 0.32 5,816.58 MWD+SC+sag (4) 9,053.00 20.75 338.03 5,560.50 5,155.99 -2,741.055,327.30 2,263,454.33 229,084.47 0.30 5,838.66 MWD+SC+sag (4) 9,115.63 20.77 338.70 5,619.06 5,176.62 -2,749.245,385.86 2,263,475.14 229,076.75 0.38 5,860.76 MWD+SC+sag (4) 9,177.63 20.50 338.19 5,677.09 5,196.95 -2,757.265,443.89 2,263,495.64 229,069.18 0.52 5,882.50 MWD+SC+sag (4) 9,239.31 20.65 340.57 5,734.83 5,217.23 -2,764.895,501.63 2,263,516.09 229,062.00 1.38 5,904.03 MWD+SC+sag (4) 9,301.09 20.41 340.68 5,792.69 5,237.67 -2,772.085,559.49 2,263,536.68 229,055.27 0.39 5,925.50 MWD+SC+sag (4) 9,363.31 20.18 341.21 5,851.05 5,258.07 -2,779.135,617.85 2,263,557.23 229,048.68 0.47 5,946.87 MWD+SC+sag (4) 9,424.62 20.02 340.61 5,908.62 5,277.98 -2,786.025,675.42 2,263,577.29 229,042.24 0.43 5,967.73 MWD+SC+sag (4) 9,487.34 20.30 340.76 5,967.50 5,298.38 -2,793.175,734.30 2,263,597.84 229,035.55 0.45 5,989.15 MWD+SC+sag (4) 9,549.30 20.32 340.71 6,025.61 5,318.68 -2,800.265,792.41 2,263,618.30 229,028.91 0.04 6,010.45 MWD+SC+sag (4) 9,611.88 20.65 340.55 6,084.23 5,339.34 -2,807.535,851.03 2,263,639.12 229,022.11 0.53 6,032.15 MWD+SC+sag (4) 9,671.91 19.53 340.05 6,140.61 5,358.75 -2,814.485,907.41 2,263,658.68 229,015.59 1.89 6,052.59 MWD+SC+sag (4) 9,734.82 19.53 340.10 6,199.90 5,378.53 -2,821.645,966.70 2,263,678.61 229,008.87 0.03 6,073.46 MWD+SC+sag (4) 9,796.42 18.90 340.75 6,258.07 5,397.63 -2,828.446,024.87 2,263,697.85 229,002.50 1.08 6,093.56 MWD+SC+sag (4) 9,859.09 18.69 341.17 6,317.39 5,416.71 -2,835.026,084.19 2,263,717.08 228,996.34 0.40 6,113.54 MWD+SC+sag (4) 9,861.79 18.72 341.19 6,319.95 5,417.53 -2,835.306,086.75 2,263,717.91 228,996.08 1.06 6,114.40 MWD+SC+sag (4) Blossom 1 - BHL tgt 9,920.68 19.33 341.58 6,375.62 5,435.72 -2,841.436,142.42 2,263,736.23 228,990.36 1.06 6,133.39 MWD+SC+sag (4) 9,982.43 19.17 342.15 6,433.92 5,455.07 -2,847.776,200.72 2,263,755.71 228,984.46 0.40 6,153.49 MWD+SC+sag (4) 10,044.63 18.89 339.31 6,492.72 5,474.21 -2,854.456,259.52 2,263,775.00 228,978.20 1.56 6,173.58 MWD+SC+sag (4) 10,106.99 19.70 337.86 6,551.58 5,493.39 -2,861.986,318.38 2,263,794.34 228,971.10 1.51 6,194.08 MWD+SC+sag (4) 10,168.62 19.17 338.07 6,609.70 5,512.40 -2,869.686,376.50 2,263,813.52 228,963.83 0.87 6,214.50 MWD+SC+sag (4) 7/16/2015 6:42:37PM COMPASS 5000.1 Build 73 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Rig: Blossom #1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,230.86 19.14 339.09 6,668.49 5,531.41 -2,877.136,435.29 2,263,832.69 228,956.80 0.54 6,234.82 MWD+SC+sag (4) 10,292.81 19.22 339.61 6,727.00 5,550.46 -2,884.316,493.80 2,263,851.89 228,950.05 0.30 6,255.05 MWD+SC+sag (4) 10,354.73 18.71 340.86 6,785.56 5,569.39 -2,891.126,552.36 2,263,870.97 228,943.67 1.05 6,275.00 MWD+SC+sag (4) 10,415.30 19.50 339.00 6,842.80 5,588.01 -2,897.936,609.60 2,263,889.73 228,937.28 1.65 6,294.67 MWD+SC+sag (4) 10,478.91 19.75 338.03 6,902.71 5,607.89 -2,905.756,669.51 2,263,909.78 228,929.90 0.65 6,315.93 MWD+SC+sag (4) 10,541.69 20.14 337.76 6,961.73 5,627.73 -2,913.816,728.53 2,263,929.80 228,922.28 0.64 6,337.27 MWD+SC+sag (4) 10,603.73 20.59 337.60 7,019.89 5,647.70 -2,922.016,786.69 2,263,949.95 228,914.53 0.73 6,358.78 MWD+SC+sag (4) 10,665.86 18.80 338.42 7,078.38 5,667.11 -2,929.866,845.18 2,263,969.53 228,907.12 2.92 6,379.63 MWD+SC+sag (4) 10,728.60 18.28 339.83 7,137.87 5,685.75 -2,936.976,904.67 2,263,988.32 228,900.43 1.09 6,399.46 MWD+SC+sag (4) 10,791.96 18.18 341.11 7,198.05 5,704.43 -2,943.606,964.85 2,264,007.14 228,894.22 0.65 6,419.11 MWD+SC+sag (4) 10,855.21 19.21 339.54 7,257.96 5,723.51 -2,950.437,024.76 2,264,026.37 228,887.81 1.81 6,439.21 MWD+SC+sag (4) 10,916.81 18.50 340.50 7,316.25 5,742.22 -2,957.237,083.05 2,264,045.23 228,881.43 1.26 6,458.96 MWD+SC+sag (4) 10,977.85 18.71 340.36 7,374.10 5,760.57 -2,963.767,140.90 2,264,063.72 228,875.32 0.35 6,478.26 MWD+SC+sag (4) 11,039.87 19.02 339.38 7,432.79 5,779.40 -2,970.667,199.59 2,264,082.70 228,868.84 0.71 6,498.17 MWD+SC+sag (4) 11,102.01 18.15 341.34 7,491.69 5,798.04 -2,977.327,258.49 2,264,101.49 228,862.59 1.72 6,517.80 MWD+SC+sag (4) 11,166.86 17.81 343.41 7,553.37 5,817.12 -2,983.387,320.17 2,264,120.69 228,856.95 1.12 6,537.54 MWD+SC+sag (4) 11,200.00 17.81 343.41 7,584.93 5,826.83 -2,986.287,351.73 2,264,130.47 228,854.28 0.00 6,547.51 PROJECTED to TD 5" - Blossom #1 PB1 TD Approved By:Checked By:Date: 7/16/2015 6:42:37PM COMPASS 5000.1 Build 73 Page 7 Chelsea Wright 16 July, 2015 Ninilchik Unit Blossom Blossom #1PB1 50-133-20648-70-00 50-133-20648-70-00 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Ninilchik Unit Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: Blossom #1 usft usft 0.00 0.00 2,258,238.57 231,709.77 215.20Wellhead Elevation:0.00 usft0.00 60° 10' 23.684 N 151° 28' 24.180 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) Blossom #1PB1 Model NameMagnetics BGGM2014 5/5/2015 16.46 73.18 55,197 Phase:Version: Audit Notes: Design Blossom #1PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:18.00 343.030.000.0018.00 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 7/16/2015 Survey Date MWD+SC+sag Fixed:v2:standard dec & axial correction + sag137.96 2,423.71 Blossom #1 PB1 MWD 1 (Blossom #1PB 05/01/2015 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag2,488.40 6,748.34 Blossom #1 PB1 MWD 2 (Blossom #1PB 06/29/2015 MWD+SC+sag Fixed:v2:standard dec & axial correction + sag6,827.19 12,005.60 Blossom #1 PB1 MWD 3 (Blossom #1PB 06/29/2015 MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18.00 0.00 0.00 18.00 0.00 0.00-215.20 2,258,238.57 231,709.77 0.00 0.00 UNDEFINED 137.96 0.47 356.49 137.96 0.49 -0.03-95.24 2,258,239.06 231,709.75 0.39 0.48 MWD+SC+sag (1) 193.23 0.62 356.49 193.23 1.02 -0.06-39.97 2,258,239.59 231,709.73 0.27 0.99 MWD+SC+sag (1) 260.25 3.65 331.63 260.19 3.26 -1.1026.99 2,258,241.85 231,708.74 4.62 3.43 MWD+SC+sag (1) 322.23 6.22 329.91 321.94 7.90 -3.7288.74 2,258,246.55 231,706.23 4.15 8.64 MWD+SC+sag (1) 383.82 9.01 330.69 382.98 14.99 -7.75149.78 2,258,253.73 231,702.35 4.53 16.60 MWD+SC+sag (1) 444.21 11.76 329.46 442.37 24.42 -13.20209.17 2,258,263.27 231,697.12 4.57 27.21 MWD+SC+sag (1) 504.64 14.32 329.44 501.24 36.16 -20.13268.04 2,258,275.17 231,690.45 4.24 40.46 MWD+SC+sag (1) 568.32 17.28 330.08 562.51 51.14 -28.85329.31 2,258,290.34 231,682.07 4.66 57.33 MWD+SC+sag (1) 629.58 19.73 329.56 620.60 67.94 -38.63387.40 2,258,307.36 231,672.67 4.01 76.26 MWD+SC+sag (1) 691.16 22.53 328.92 678.03 87.01 -49.99444.83 2,258,326.67 231,661.74 4.56 97.81 MWD+SC+sag (1) 753.82 25.09 329.46 735.35 108.74 -62.94502.15 2,258,348.68 231,649.27 4.10 122.37 MWD+SC+sag (1) 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 814.96 27.38 329.23 790.19 131.99 -76.72556.99 2,258,372.23 231,636.02 3.75 148.63 MWD+SC+sag (1) 877.06 30.23 329.97 844.60 157.80 -91.85611.40 2,258,398.37 231,621.46 4.63 177.73 MWD+SC+sag (1) 938.85 33.44 330.69 897.09 186.12 -107.97663.89 2,258,427.05 231,605.98 5.23 209.53 MWD+SC+sag (1) 1,000.99 36.39 330.78 948.04 217.14 -125.36714.84 2,258,458.45 231,589.29 4.75 244.27 MWD+SC+sag (1) 1,063.70 39.18 331.38 997.59 250.77 -143.93764.39 2,258,492.48 231,571.47 4.49 281.86 MWD+SC+sag (1) 1,124.86 42.16 329.96 1,043.98 285.51 -163.47810.78 2,258,527.65 231,552.72 5.10 320.79 MWD+SC+sag (1) 1,186.33 45.05 329.56 1,088.49 322.13 -184.82855.29 2,258,564.73 231,532.19 4.72 362.04 MWD+SC+sag (1) 1,249.03 48.08 330.44 1,131.59 361.56 -207.57898.39 2,258,604.66 231,510.32 4.94 406.40 MWD+SC+sag (1) 1,311.55 50.29 329.26 1,172.45 402.46 -231.34939.25 2,258,646.09 231,487.47 3.81 452.46 MWD+SC+sag (1) 1,373.34 52.53 328.92 1,210.99 443.90 -256.15977.79 2,258,688.06 231,463.59 3.65 499.33 MWD+SC+sag (1) 1,434.45 54.15 329.45 1,247.48 486.00 -281.261,014.28 2,258,730.71 231,439.43 2.74 546.93 MWD+SC+sag (1) 1,495.98 57.11 329.38 1,282.21 529.71 -307.101,049.01 2,258,774.99 231,414.57 4.81 596.28 MWD+SC+sag (1) 1,558.19 61.14 329.70 1,314.13 575.73 -334.161,080.93 2,258,821.60 231,388.54 6.49 648.19 MWD+SC+sag (1) 1,620.81 63.35 329.98 1,343.29 623.64 -362.001,110.09 2,258,870.12 231,361.78 3.55 702.14 MWD+SC+sag (1) 1,681.65 67.29 330.96 1,368.68 671.74 -389.231,135.48 2,258,918.81 231,335.63 6.64 756.09 MWD+SC+sag (1) 1,743.66 71.15 331.97 1,390.68 722.66 -416.921,157.48 2,258,970.34 231,309.09 6.41 812.88 MWD+SC+sag (1) 1,805.85 74.49 332.18 1,409.05 775.15 -444.741,175.85 2,259,023.44 231,282.44 5.38 871.21 MWD+SC+sag (1) 1,868.60 75.97 331.80 1,425.04 828.72 -473.231,191.84 2,259,077.63 231,255.15 2.43 930.76 MWD+SC+sag (1) 1,930.01 77.16 331.61 1,439.31 881.31 -501.541,206.11 2,259,130.84 231,228.02 1.96 989.32 MWD+SC+sag (1) 1,990.97 76.62 332.10 1,453.14 933.66 -529.551,219.94 2,259,183.80 231,201.19 1.18 1,047.57 MWD+SC+sag (1) 2,054.34 74.47 332.56 1,468.96 988.00 -558.051,235.76 2,259,238.76 231,173.91 3.46 1,107.86 MWD+SC+sag (1) 2,116.65 73.19 332.71 1,486.31 1,041.15 -585.551,253.11 2,259,292.51 231,147.60 2.07 1,166.72 MWD+SC+sag (1) 2,178.22 73.53 330.07 1,503.94 1,092.93 -613.801,270.74 2,259,344.91 231,120.52 4.15 1,224.50 MWD+SC+sag (1) 2,240.18 73.88 329.53 1,521.33 1,144.33 -643.711,288.13 2,259,396.96 231,091.76 1.01 1,282.39 MWD+SC+sag (1) 2,301.32 75.98 329.08 1,537.22 1,195.10 -673.851,304.02 2,259,448.38 231,062.76 3.51 1,339.74 MWD+SC+sag (1) 2,363.14 76.12 329.37 1,552.13 1,246.64 -704.551,318.93 2,259,500.60 231,033.22 0.51 1,398.00 MWD+SC+sag (1) 2,423.71 74.98 329.94 1,567.24 1,297.26 -734.181,334.04 2,259,551.86 231,004.73 2.09 1,455.06 MWD+SC+sag (1) 2,488.40 75.15 330.52 1,583.91 1,351.52 -765.221,350.71 2,259,606.80 230,974.91 0.91 1,516.01 MWD+SC+sag (2) 2,495.00 75.03 330.58 1,585.61 1,357.07 -768.351,352.41 2,259,612.42 230,971.90 1.95 1,522.24 MWD+SC+sag (2) 10 3/4" 2,550.18 74.07 331.07 1,600.31 1,403.51 -794.281,367.11 2,259,659.42 230,947.01 1.95 1,574.22 MWD+SC+sag (2) 2,610.36 73.37 330.84 1,617.18 1,454.01 -822.321,383.98 2,259,710.54 230,920.10 1.22 1,630.71 MWD+SC+sag (2) 2,674.52 72.47 331.45 1,636.02 1,507.72 -851.921,402.82 2,259,764.90 230,891.71 1.67 1,690.73 MWD+SC+sag (2) 2,736.22 72.98 331.39 1,654.35 1,559.46 -880.111,421.15 2,259,817.25 230,864.69 0.83 1,748.44 MWD+SC+sag (2) 2,795.57 73.54 330.36 1,671.44 1,609.11 -907.771,438.24 2,259,867.50 230,838.14 1.91 1,804.00 MWD+SC+sag (2) 2,857.65 72.74 331.45 1,689.45 1,661.02 -936.661,456.25 2,259,920.04 230,810.42 2.12 1,862.08 MWD+SC+sag (2) 2,919.60 75.99 329.44 1,706.14 1,712.90 -966.091,472.94 2,259,972.57 230,782.15 6.11 1,920.29 MWD+SC+sag (2) 2,981.31 76.37 329.17 1,720.88 1,764.43 -996.681,487.68 2,260,024.76 230,752.72 0.75 1,978.50 MWD+SC+sag (2) 3,043.14 77.20 329.36 1,735.02 1,816.17 -1,027.441,501.82 2,260,077.17 230,723.12 1.38 2,036.97 MWD+SC+sag (2) 3,105.40 76.17 329.33 1,749.36 1,868.29 -1,058.331,516.16 2,260,129.97 230,693.40 1.66 2,095.83 MWD+SC+sag (2) 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,168.37 76.94 329.55 1,764.00 1,921.02 -1,089.471,530.80 2,260,183.39 230,663.45 1.27 2,155.36 MWD+SC+sag (2) 3,229.29 76.88 329.78 1,777.79 1,972.24 -1,119.441,544.59 2,260,235.25 230,634.63 0.38 2,213.09 MWD+SC+sag (2) 3,291.55 77.19 329.41 1,791.76 2,024.56 -1,150.141,558.56 2,260,288.25 230,605.10 0.76 2,272.10 MWD+SC+sag (2) 3,353.80 77.63 329.46 1,805.33 2,076.88 -1,181.041,572.13 2,260,341.24 230,575.38 0.71 2,331.16 MWD+SC+sag (2) 3,415.63 76.10 329.75 1,819.38 2,128.81 -1,211.501,586.18 2,260,393.84 230,546.08 2.52 2,389.72 MWD+SC+sag (2) 3,478.20 76.23 329.47 1,834.34 2,181.22 -1,242.241,601.14 2,260,446.92 230,516.52 0.48 2,448.82 MWD+SC+sag (2) 3,537.60 76.00 329.59 1,848.60 2,230.92 -1,271.481,615.40 2,260,497.26 230,488.40 0.43 2,504.89 MWD+SC+sag (2) 3,601.71 75.41 329.04 1,864.43 2,284.35 -1,303.181,631.23 2,260,551.38 230,457.90 1.24 2,565.24 MWD+SC+sag (2) 3,663.09 76.25 328.34 1,879.45 2,335.19 -1,334.111,646.25 2,260,602.90 230,428.11 1.76 2,622.90 MWD+SC+sag (2) 3,725.67 76.43 329.07 1,894.23 2,387.15 -1,365.691,661.03 2,260,655.55 230,397.69 1.17 2,681.82 MWD+SC+sag (2) 3,786.41 77.36 329.38 1,908.00 2,437.98 -1,395.961,674.80 2,260,707.04 230,368.57 1.61 2,739.26 MWD+SC+sag (2) 3,849.33 77.38 330.01 1,921.76 2,490.99 -1,426.941,688.56 2,260,760.72 230,338.78 0.98 2,799.01 MWD+SC+sag (2) 3,911.09 76.57 329.17 1,935.68 2,542.88 -1,457.401,702.48 2,260,813.28 230,309.49 1.86 2,857.53 MWD+SC+sag (2) 3,973.03 77.19 330.13 1,949.74 2,594.93 -1,487.881,716.54 2,260,866.00 230,280.18 1.81 2,916.21 MWD+SC+sag (2) 4,035.23 77.49 331.19 1,963.37 2,647.84 -1,517.621,730.17 2,260,919.56 230,251.63 1.73 2,975.49 MWD+SC+sag (2) 4,097.74 75.41 331.04 1,978.02 2,701.04 -1,546.971,744.82 2,260,973.40 230,223.47 3.34 3,034.95 MWD+SC+sag (2) 4,159.36 75.98 330.76 1,993.24 2,753.22 -1,576.011,760.04 2,261,026.21 230,195.60 1.02 3,093.33 MWD+SC+sag (2) 4,221.78 76.61 330.86 2,008.03 2,806.16 -1,605.581,774.83 2,261,079.80 230,167.22 1.02 3,152.59 MWD+SC+sag (2) 4,283.52 76.43 330.57 2,022.42 2,858.52 -1,634.951,789.22 2,261,132.80 230,139.02 0.54 3,211.25 MWD+SC+sag (2) 4,345.49 76.44 329.74 2,036.96 2,910.77 -1,664.931,803.76 2,261,185.71 230,110.22 1.30 3,269.98 MWD+SC+sag (2) 4,407.48 75.84 330.18 2,051.81 2,962.87 -1,695.061,818.61 2,261,238.47 230,081.26 1.19 3,328.60 MWD+SC+sag (2) 4,468.53 75.76 330.09 2,066.79 3,014.20 -1,724.531,833.59 2,261,290.44 230,052.94 0.19 3,386.30 MWD+SC+sag (2) 4,530.89 76.66 330.31 2,081.65 3,066.75 -1,754.631,848.45 2,261,343.65 230,024.03 1.48 3,445.35 MWD+SC+sag (2) 4,592.56 76.88 329.91 2,095.76 3,118.80 -1,784.541,862.56 2,261,396.35 229,995.28 0.73 3,503.86 MWD+SC+sag (2) 4,654.67 76.51 330.30 2,110.06 3,171.20 -1,814.671,876.86 2,261,449.41 229,966.33 0.85 3,562.77 MWD+SC+sag (2) 4,716.73 77.58 329.62 2,123.97 3,223.56 -1,844.951,890.77 2,261,502.42 229,937.23 2.03 3,621.68 MWD+SC+sag (2) 4,779.45 77.45 330.15 2,137.53 3,276.53 -1,875.671,904.33 2,261,556.07 229,907.69 0.85 3,681.31 MWD+SC+sag (2) 4,840.09 76.57 330.45 2,151.16 3,327.85 -1,904.951,917.96 2,261,608.03 229,879.57 1.53 3,738.95 MWD+SC+sag (2) 4,902.91 77.26 329.78 2,165.38 3,380.90 -1,935.441,932.18 2,261,661.75 229,850.27 1.51 3,798.59 MWD+SC+sag (2) 4,964.88 77.18 329.57 2,179.09 3,433.07 -1,965.951,945.89 2,261,714.58 229,820.93 0.35 3,857.39 MWD+SC+sag (2) 5,026.85 76.75 329.82 2,193.07 3,485.19 -1,996.411,959.87 2,261,767.37 229,791.64 0.80 3,916.13 MWD+SC+sag (2) 5,089.13 76.42 329.51 2,207.52 3,537.48 -2,027.011,974.32 2,261,820.32 229,762.22 0.72 3,975.07 MWD+SC+sag (2) 5,150.87 74.14 331.37 2,223.21 3,589.41 -2,056.471,990.01 2,261,872.90 229,733.92 4.70 4,033.34 MWD+SC+sag (2) 5,182.49 73.20 331.99 2,232.10 3,616.12 -2,070.861,998.90 2,261,899.92 229,720.13 3.53 4,063.09 MWD+SC+sag (2) Blossom 1 - Beluga T-1 tgt 5,211.25 72.34 332.56 2,240.62 3,640.44 -2,083.642,007.42 2,261,924.52 229,707.89 3.53 4,090.08 MWD+SC+sag (2) 5,273.84 70.00 333.06 2,260.82 3,693.13 -2,110.712,027.62 2,261,977.80 229,682.01 3.81 4,148.38 MWD+SC+sag (2) 5,336.37 66.55 333.53 2,283.96 3,745.01 -2,136.822,050.76 2,262,030.25 229,657.07 5.56 4,205.62 MWD+SC+sag (2) 5,397.51 64.22 333.93 2,309.42 3,794.85 -2,161.422,076.22 2,262,080.62 229,633.59 3.86 4,260.47 MWD+SC+sag (2) 5,459.54 60.93 334.98 2,337.99 3,844.51 -2,185.162,104.79 2,262,130.81 229,610.95 5.51 4,314.90 MWD+SC+sag (2) 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 5,521.73 58.01 335.98 2,369.58 3,893.24 -2,207.402,136.38 2,262,180.02 229,589.81 4.90 4,368.00 MWD+SC+sag (2) 5,583.84 55.06 336.28 2,403.82 3,940.62 -2,228.372,170.62 2,262,227.85 229,569.91 4.77 4,419.43 MWD+SC+sag (2) 5,646.10 51.99 335.76 2,440.83 3,986.36 -2,248.712,207.63 2,262,274.03 229,550.59 4.98 4,469.11 MWD+SC+sag (2) 5,707.72 49.10 335.36 2,479.99 4,029.67 -2,268.392,246.79 2,262,317.77 229,531.89 4.72 4,516.28 MWD+SC+sag (2) 5,769.13 46.80 335.29 2,521.11 4,071.10 -2,287.422,287.91 2,262,359.62 229,513.78 3.75 4,561.47 MWD+SC+sag (2) 5,800.27 45.43 335.72 2,542.70 4,091.53 -2,296.732,309.50 2,262,380.24 229,504.93 4.50 4,583.72 MWD+SC+sag (2) Blossom 1 - Beluga T-1 tgt wp3b 5,832.11 44.04 336.19 2,565.32 4,111.99 -2,305.862,332.12 2,262,400.90 229,496.26 4.50 4,605.96 MWD+SC+sag (2) 5,893.66 41.60 336.98 2,610.46 4,150.38 -2,322.492,377.26 2,262,439.65 229,480.49 4.06 4,647.53 MWD+SC+sag (2) 5,954.93 38.68 336.99 2,657.29 4,186.73 -2,337.932,424.09 2,262,476.33 229,465.87 4.77 4,686.80 MWD+SC+sag (2) 6,016.03 36.18 336.04 2,705.81 4,220.79 -2,352.722,472.61 2,262,510.72 229,451.84 4.20 4,723.69 MWD+SC+sag (2) 6,078.10 34.39 334.81 2,756.48 4,253.39 -2,367.622,523.28 2,262,543.65 229,437.67 3.10 4,759.23 MWD+SC+sag (2) 6,140.90 31.27 336.00 2,809.24 4,284.34 -2,381.802,576.04 2,262,574.90 229,424.18 5.07 4,792.97 MWD+SC+sag (2) 6,202.47 28.79 336.59 2,862.54 4,312.55 -2,394.192,629.34 2,262,603.38 229,412.42 4.06 4,823.57 MWD+SC+sag (2) 6,264.19 25.13 336.12 2,917.54 4,338.18 -2,405.412,684.34 2,262,629.25 229,401.78 5.94 4,851.35 MWD+SC+sag (2) 6,327.13 21.92 336.33 2,975.24 4,361.17 -2,415.542,742.04 2,262,652.46 229,392.17 5.10 4,876.30 MWD+SC+sag (2) 6,388.54 19.62 335.06 3,032.66 4,381.02 -2,424.492,799.46 2,262,672.50 229,383.66 3.82 4,897.89 MWD+SC+sag (2) 6,451.05 19.95 335.28 3,091.48 4,400.22 -2,433.372,858.28 2,262,691.90 229,375.21 0.54 4,918.85 MWD+SC+sag (2) 6,513.77 19.66 335.22 3,150.49 4,419.52 -2,442.272,917.29 2,262,711.39 229,366.75 0.46 4,939.91 MWD+SC+sag (2) 6,576.51 19.58 335.75 3,209.59 4,438.68 -2,451.012,976.39 2,262,730.75 229,358.43 0.31 4,960.79 MWD+SC+sag (2) 6,638.20 19.51 335.77 3,267.72 4,457.50 -2,459.483,034.52 2,262,749.75 229,350.38 0.11 4,981.27 MWD+SC+sag (2) 6,700.75 19.46 336.00 3,326.69 4,476.55 -2,468.013,093.49 2,262,768.98 229,342.29 0.15 5,001.97 MWD+SC+sag (2) 6,748.34 19.33 336.25 3,371.58 4,491.00 -2,474.413,138.38 2,262,783.57 229,336.21 0.32 5,017.66 MWD+SC+sag (2) 6,785.00 19.34 336.86 3,406.17 4,502.13 -2,479.233,172.97 2,262,794.81 229,331.63 0.55 5,029.72 MWD+SC+sag (3) 7 5/8" 6,827.19 19.35 337.57 3,445.98 4,515.02 -2,484.653,212.78 2,262,807.81 229,326.51 0.55 5,043.62 MWD+SC+sag (3) 6,890.71 20.22 337.97 3,505.75 4,534.92 -2,492.783,272.55 2,262,827.89 229,318.83 1.39 5,065.03 MWD+SC+sag (3) 6,957.84 20.64 339.17 3,568.66 4,556.73 -2,501.343,335.46 2,262,849.89 229,310.76 0.88 5,088.39 MWD+SC+sag (3) 7,019.51 19.74 339.02 3,626.54 4,576.62 -2,508.933,393.34 2,262,869.94 229,303.61 1.46 5,109.62 MWD+SC+sag (3) 7,085.81 20.23 339.14 3,688.85 4,597.78 -2,517.023,455.65 2,262,891.28 229,295.99 0.74 5,132.23 MWD+SC+sag (3) 7,147.01 19.20 339.46 3,746.46 4,617.09 -2,524.323,513.26 2,262,910.75 229,289.12 1.69 5,152.83 MWD+SC+sag (3) 7,214.06 19.98 339.92 3,809.63 4,638.18 -2,532.123,576.43 2,262,932.00 229,281.80 1.19 5,175.27 MWD+SC+sag (3) 7,276.39 18.61 339.54 3,868.45 4,657.50 -2,539.253,635.25 2,262,951.47 229,275.10 2.21 5,195.84 MWD+SC+sag (3) 7,342.39 19.06 339.77 3,930.92 4,677.48 -2,546.663,697.72 2,262,971.61 229,268.14 0.69 5,217.11 MWD+SC+sag (3) 7,404.18 19.55 340.25 3,989.23 4,696.67 -2,553.643,756.03 2,262,990.96 229,261.58 0.83 5,237.51 MWD+SC+sag (3) 7,470.82 18.38 336.39 4,052.26 4,716.80 -2,561.623,819.06 2,263,011.25 229,254.06 2.57 5,259.08 MWD+SC+sag (3) 7,532.63 18.83 336.05 4,110.84 4,734.84 -2,569.573,877.64 2,263,029.47 229,246.51 0.75 5,278.66 MWD+SC+sag (3) 7,598.48 19.16 336.29 4,173.10 4,754.45 -2,578.233,939.90 2,263,049.27 229,238.29 0.51 5,299.94 MWD+SC+sag (3) 7,659.57 19.74 336.18 4,230.71 4,773.06 -2,586.433,997.51 2,263,068.06 229,230.51 0.95 5,320.14 MWD+SC+sag (3) 7,726.30 20.16 335.74 4,293.43 4,793.86 -2,595.714,060.23 2,263,089.05 229,221.70 0.67 5,342.73 MWD+SC+sag (3) 7,788.73 18.50 337.18 4,352.34 4,812.80 -2,603.974,119.14 2,263,108.17 229,213.86 2.77 5,363.26 MWD+SC+sag (3) 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 7,805.00 18.51 337.17 4,367.77 4,817.56 -2,605.974,134.57 2,263,112.97 229,211.97 0.04 5,368.40 MWD+SC+sag (3) Top of Fish 7,847.75 18.52 337.13 4,408.31 4,830.06 -2,611.244,175.11 2,263,125.60 229,206.98 0.04 5,381.90 MWD+SC+sag (3) 7,910.75 18.81 337.43 4,467.99 4,848.66 -2,619.034,234.79 2,263,144.36 229,199.61 0.48 5,401.96 MWD+SC+sag (3) 7,971.86 18.86 337.07 4,525.83 4,866.86 -2,626.664,292.63 2,263,162.72 229,192.39 0.21 5,421.59 MWD+SC+sag (3) 8,036.31 19.04 337.00 4,586.79 4,886.13 -2,634.824,353.59 2,263,182.17 229,184.65 0.28 5,442.40 MWD+SC+sag (3) 8,098.28 18.99 336.78 4,645.38 4,904.70 -2,642.754,412.18 2,263,200.91 229,177.14 0.14 5,462.48 MWD+SC+sag (3) 8,159.82 19.35 337.20 4,703.50 4,923.30 -2,650.654,470.30 2,263,219.68 229,169.66 0.63 5,482.57 MWD+SC+sag (3) 8,222.43 19.39 336.78 4,762.57 4,942.41 -2,658.774,529.37 2,263,238.97 229,161.97 0.23 5,503.22 MWD+SC+sag (3) 8,284.03 19.64 336.94 4,820.63 4,961.33 -2,666.854,587.43 2,263,258.07 229,154.31 0.42 5,523.68 MWD+SC+sag (3) 8,346.30 20.13 336.93 4,879.19 4,980.82 -2,675.154,645.99 2,263,277.74 229,146.45 0.79 5,544.74 MWD+SC+sag (3) 8,408.31 18.29 336.93 4,937.74 4,999.59 -2,683.144,704.54 2,263,296.68 229,138.88 2.97 5,565.03 MWD+SC+sag (3) 8,469.74 18.57 337.26 4,996.02 5,017.48 -2,690.704,762.82 2,263,314.74 229,131.72 0.49 5,584.35 MWD+SC+sag (3) 8,532.03 18.69 337.45 5,055.05 5,035.84 -2,698.364,821.85 2,263,333.27 229,124.47 0.22 5,604.15 MWD+SC+sag (3) 8,593.38 19.01 337.87 5,113.11 5,054.18 -2,705.904,879.91 2,263,351.76 229,117.35 0.57 5,623.88 MWD+SC+sag (3) 8,655.54 19.66 338.31 5,171.76 5,073.27 -2,713.584,938.56 2,263,371.02 229,110.10 1.07 5,644.39 MWD+SC+sag (3) 8,681.20 19.77 338.06 5,195.92 5,081.31 -2,716.794,962.72 2,263,379.13 229,107.06 0.53 5,653.01 MWD+SC+sag (3) Blossom 1 - Tyonek T-1 tgt 8,716.35 19.91 337.71 5,228.98 5,092.36 -2,721.284,995.78 2,263,390.28 229,102.82 0.53 5,664.89 MWD+SC+sag (3) 8,778.17 18.37 336.15 5,287.38 5,111.01 -2,729.225,054.18 2,263,409.10 229,095.30 2.62 5,685.04 MWD+SC+sag (3) 8,841.20 18.42 336.65 5,347.19 5,129.24 -2,737.185,113.99 2,263,427.50 229,087.75 0.26 5,704.80 MWD+SC+sag (3) 8,903.51 18.62 336.81 5,406.28 5,147.42 -2,745.005,173.08 2,263,445.85 229,080.34 0.33 5,724.47 MWD+SC+sag (3) 8,965.11 18.34 336.87 5,464.70 5,165.37 -2,752.685,231.50 2,263,463.97 229,073.06 0.46 5,743.88 MWD+SC+sag (3) 9,027.46 19.17 334.49 5,523.74 5,183.63 -2,760.945,290.54 2,263,482.41 229,065.21 1.81 5,763.76 MWD+SC+sag (3) 9,088.42 19.44 334.30 5,581.27 5,201.80 -2,769.655,348.07 2,263,500.77 229,056.91 0.45 5,783.69 MWD+SC+sag (3) 9,150.06 19.80 334.53 5,639.33 5,220.47 -2,778.595,406.13 2,263,519.63 229,048.39 0.60 5,804.15 MWD+SC+sag (3) 9,212.11 19.67 335.05 5,697.74 5,239.43 -2,787.515,464.54 2,263,538.79 229,039.89 0.35 5,824.89 MWD+SC+sag (3) 9,273.43 20.10 335.45 5,755.40 5,258.37 -2,796.245,522.20 2,263,557.92 229,031.58 0.74 5,845.55 MWD+SC+sag (3) 9,336.20 20.00 334.83 5,814.37 5,277.90 -2,805.295,581.17 2,263,577.64 229,022.97 0.37 5,866.87 MWD+SC+sag (3) 9,397.93 20.33 334.41 5,872.31 5,297.12 -2,814.415,639.11 2,263,597.06 229,014.28 0.58 5,887.92 MWD+SC+sag (3) 9,460.25 20.46 334.43 5,930.73 5,316.71 -2,823.795,697.53 2,263,616.86 229,005.34 0.21 5,909.39 MWD+SC+sag (3) 9,521.00 20.80 334.69 5,987.58 5,336.04 -2,832.985,754.38 2,263,636.38 228,996.58 0.58 5,930.56 MWD+SC+sag (3) 9,583.84 20.86 333.39 6,046.32 5,356.13 -2,842.765,813.12 2,263,656.69 228,987.25 0.74 5,952.63 MWD+SC+sag (3) 9,646.02 21.37 333.44 6,104.32 5,376.16 -2,852.795,871.12 2,263,676.94 228,977.68 0.82 5,974.72 MWD+SC+sag (3) 9,708.39 21.58 332.86 6,162.36 5,396.53 -2,863.105,929.16 2,263,697.53 228,967.82 0.48 5,997.21 MWD+SC+sag (3) 9,769.13 22.11 332.86 6,218.74 5,416.64 -2,873.415,985.54 2,263,717.87 228,957.96 0.87 6,019.46 MWD+SC+sag (3) 9,831.97 22.31 333.05 6,276.92 5,437.80 -2,884.216,043.72 2,263,739.26 228,947.64 0.34 6,042.84 MWD+SC+sag (3) 9,861.64 22.00 332.76 6,304.39 5,447.76 -2,889.316,071.19 2,263,749.33 228,942.77 1.10 6,053.86 MWD+SC+sag (3) Blossom 1 - BHL tgt 9,893.60 21.67 332.44 6,334.06 5,458.32 -2,894.786,100.86 2,263,760.01 228,937.53 1.10 6,065.55 MWD+SC+sag (3) 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 9,956.24 21.23 335.60 6,392.37 5,478.90 -2,904.816,159.17 2,263,780.81 228,927.96 1.97 6,088.17 MWD+SC+sag (3) 10,018.73 21.66 336.84 6,450.53 5,499.80 -2,914.026,217.33 2,263,801.91 228,919.22 1.00 6,110.85 MWD+SC+sag (3) 10,080.43 21.95 337.63 6,507.82 5,520.94 -2,922.896,274.62 2,263,823.24 228,910.82 0.67 6,133.65 MWD+SC+sag (3) 10,142.90 22.16 338.53 6,565.71 5,542.70 -2,931.656,332.51 2,263,845.19 228,902.56 0.64 6,157.02 MWD+SC+sag (3) 10,204.21 20.58 337.84 6,622.81 5,563.44 -2,939.946,389.61 2,263,866.11 228,894.72 2.61 6,179.28 MWD+SC+sag (3) 10,265.63 20.44 338.40 6,680.33 5,583.41 -2,947.966,447.13 2,263,886.25 228,887.15 0.39 6,200.72 MWD+SC+sag (3) 10,327.44 20.87 339.17 6,738.17 5,603.74 -2,955.856,504.97 2,263,906.75 228,879.72 0.82 6,222.46 MWD+SC+sag (3) 10,389.97 21.52 339.49 6,796.47 5,624.89 -2,963.836,563.27 2,263,928.07 228,872.21 1.06 6,245.02 MWD+SC+sag (3) 10,452.58 19.64 338.69 6,855.08 5,645.45 -2,971.686,621.88 2,263,948.80 228,864.83 3.04 6,266.98 MWD+SC+sag (3) 10,514.38 20.18 337.12 6,913.19 5,664.94 -2,979.606,679.99 2,263,968.47 228,857.34 1.23 6,287.94 MWD+SC+sag (3) 10,576.42 19.72 337.08 6,971.51 5,684.44 -2,987.846,738.31 2,263,988.15 228,849.54 0.74 6,308.99 MWD+SC+sag (3) 10,638.40 20.51 337.79 7,029.70 5,704.13 -2,996.016,796.50 2,264,008.01 228,841.81 1.33 6,330.21 MWD+SC+sag (3) 10,699.38 21.23 337.67 7,086.68 5,724.23 -3,004.256,853.48 2,264,028.29 228,834.03 1.18 6,351.84 MWD+SC+sag (3) 10,762.32 20.83 338.29 7,145.43 5,745.17 -3,012.716,912.23 2,264,049.41 228,826.03 0.73 6,374.34 MWD+SC+sag (3) 10,823.87 21.14 338.90 7,202.90 5,765.69 -3,020.766,969.70 2,264,070.11 228,818.44 0.62 6,396.31 MWD+SC+sag (3) 10,889.56 19.11 337.57 7,264.58 5,786.68 -3,029.137,031.38 2,264,091.28 228,810.54 3.17 6,418.83 MWD+SC+sag (3) 10,952.33 19.32 337.14 7,323.85 5,805.75 -3,037.087,090.65 2,264,110.52 228,803.02 0.40 6,439.39 MWD+SC+sag (3) 11,013.49 19.41 338.44 7,381.55 5,824.52 -3,044.757,148.35 2,264,129.46 228,795.77 0.72 6,459.58 MWD+SC+sag (3) 11,075.46 19.61 338.92 7,439.96 5,843.80 -3,052.277,206.76 2,264,148.91 228,788.68 0.41 6,480.22 MWD+SC+sag (3) 11,137.81 19.96 339.44 7,498.63 5,863.53 -3,059.777,265.43 2,264,168.79 228,781.62 0.63 6,501.28 MWD+SC+sag (3) 11,199.11 19.14 340.92 7,556.40 5,882.82 -3,066.737,323.20 2,264,188.24 228,775.10 1.56 6,521.76 MWD+SC+sag (3) 11,261.75 18.56 343.11 7,615.68 5,902.07 -3,072.987,382.48 2,264,207.62 228,769.27 1.46 6,542.00 MWD+SC+sag (3) 11,324.12 18.40 344.89 7,674.83 5,921.07 -3,078.437,441.63 2,264,226.74 228,764.25 0.94 6,561.76 MWD+SC+sag (3) 11,386.40 17.81 347.55 7,734.03 5,939.86 -3,083.057,500.83 2,264,245.62 228,760.05 1.63 6,581.08 MWD+SC+sag (3) 11,448.30 17.10 350.82 7,793.08 5,958.09 -3,086.547,559.88 2,264,263.93 228,756.97 1.96 6,599.53 MWD+SC+sag (3) 11,510.18 17.77 349.77 7,852.12 5,976.36 -3,089.677,618.92 2,264,282.26 228,754.25 1.20 6,617.92 MWD+SC+sag (3) 11,572.56 17.83 349.25 7,911.51 5,995.11 -3,093.147,678.31 2,264,301.09 228,751.20 0.27 6,636.87 MWD+SC+sag (3) 11,634.04 18.21 350.24 7,969.97 6,013.83 -3,096.537,736.77 2,264,319.87 228,748.23 0.79 6,655.76 MWD+SC+sag (3) 11,696.49 18.87 350.83 8,029.18 6,033.42 -3,099.797,795.98 2,264,339.53 228,745.40 1.10 6,675.45 MWD+SC+sag (3) 11,757.59 19.19 351.62 8,086.94 6,053.10 -3,102.837,853.74 2,264,359.28 228,742.81 0.67 6,695.16 MWD+SC+sag (3) 11,818.69 19.40 352.86 8,144.61 6,073.11 -3,105.557,911.41 2,264,379.34 228,740.53 0.75 6,715.09 MWD+SC+sag (3) 11,879.59 19.51 354.00 8,202.03 6,093.26 -3,107.877,968.83 2,264,399.53 228,738.66 0.65 6,735.04 MWD+SC+sag (3) 11,942.91 19.85 354.30 8,261.66 6,114.47 -3,110.058,028.46 2,264,420.79 228,736.96 0.56 6,755.97 MWD+SC+sag (3) 12,005.60 20.08 354.89 8,320.58 6,135.78 -3,112.068,087.38 2,264,442.14 228,735.42 0.49 6,776.94 MWD+SC+sag (3) 12,006.90 20.08 354.89 8,321.80 6,136.22 -3,112.108,088.60 2,264,442.58 228,735.39 0.00 6,777.37 PROJECTED to TD AM-241 Source 12,021.64 20.08 354.89 8,335.64 6,141.27 -3,112.558,102.44 2,264,447.63 228,735.05 0.00 6,782.32 PROJECTED to TD CS 137 Source 12,098.00 20.08 354.89 8,407.36 6,167.38 -3,114.898,174.16 2,264,473.79 228,733.30 0.00 6,807.98 PROJECTED to TD Btm of Fish 12,099.00 20.08 354.89 8,408.30 6,167.72 -3,114.928,175.10 2,264,474.13 228,733.28 0.00 6,808.32 PROJECTED to TD 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Hilcorp Energy Company Ninilchik Unit Blossom Halliburton Definitive Survey Report Well: Wellbore: Blossom #1 Blossom #1PB1 Survey Calculation Method:Minimum Curvature Actual: Blossom #1 @ 233.20usft Design:Blossom #1PB1 Database:Sperry EDM - NORTH US + CANADA MD Reference:Actual: Blossom #1 @ 233.20usft North Reference: Well Blossom #1 True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name Approved By:Checked By:Date: 7/16/2015 6:39:56PM COMPASS 5000.1 Build 73 Page 8 Chelsea Wright
