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Home My WebLink About215-118STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:2/13/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2151180 Sundry #322-705 Operation:Drilling:Workover:x Explor.: Test:Initial:Weekly:x Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:869 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11" 5M P Pit Level Indicators P P #1 Rams 1 2 7/8" x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector NT NT #3 Rams 0 NA H2S Gas Detector NT NT #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16" 5M P Time/Pressure Test Result HCR Valves 1 2 1/16" 5M P System Pressure (psi)3000 P Kill Line Valves 3 2 1/16" 5M P Pressure After Closure (psi)1750 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 0 NA Full Pressure Attained (sec)63 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 x 2100 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 20 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2-13-23/07:08 Waived By Test Start Date/Time:2/13/2023 5:00 (date)(time)Witness Test Finish Date/Time:2/13/2023 10:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp Tested w/ 3-1/2" test joint. NT on Gas Dection last test was on 2/7/23. Bottle pre-charge = 1,000 PSI C.Pace / J. Werlinger Hilcorp Alaska LLC S.Heim / W. Hudgens MPU L-46 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2023-0213_BOP_Hilcorp_ASR1_MPU_L-46           J. Regg; 6/12/2023 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT L-46 JBR 03/31/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tested with 2 7/8" test joint, test #7 had a leaky test hose, swap hose good test. Comms were not hooked up at time of test. PVT's were conducted and passed later in the day after electricians could hook up comms. Test finished @ 2100 hrs when comms were finished being tested and I was contacted. Test Results TEST DATA Rig Rep:Colt PaceOperator:Hilcorp Alaska, LLC Operator Rep:Russul Gallen Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:2151180 DATE:2/7/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSTS230207063433 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 11 MASP: 869 Sundry No: 322-705 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 vari 2 7/8" x 5 P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 2 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1750 200 PSI Attained P18 Full Pressure Attained P62 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4/2225 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P15 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill NA0      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: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,690 feet N/A feet true vertical 4,177 feet N/A feet Effective Depth measured 13,690 feet feet true vertical 4,177 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 EUE 4,124' 3,332' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A 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: Operations Manager Contact Phone: 6,417, 9,603 & 10,217 4,157, 4,168 & 4,198' LTP & (2) Swell Packers 322-705 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 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) 200 Gas-Mcf MD 80' 0 Size 80' 4,174' 1489 360202 0 00 321 measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 215-118 50-029-23551-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0315848, ADL0025509 & ADL0025515 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT L-46 Plugs Junk measured Length 7,271' Casing Conductor 4,177'13,688' 6,386' 6,620'Surface Production Liner 20" 9-5/8" 7-5/8" 80' 6,589' 6,390psi 5,750psi 6,890psi 7,740psi 6,423' 4,156' Burst N/A Collapse N/A 3,090psi 4,790psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Taylor Wellman for David Haakinson Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2023.03.17 12:58:51 -08'00' Taylor Wellman (2143) RBDMS JSB 032123 322-705 Sundry Number MILNE POINT / SCHRADER BLUFF OIL ESP Swap Pull Tubing MILNE PT UNIT L-46 215-118 DSR=3/20/23 Repair Well WCB 11-27-2023 ___________________________________________________________________________________ Revised by TDF 3/17/2023 Milne Point Unit Well: MP L-46 PTD: 215-118 API: 50-029-23551-00-00 Last Completed: SCHEMATIC RKB: 27’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 78.6 A-53 Weld 19.25” Surf 80’ 9-5/8" Surf. Csg 40 L-80 TC II 8.835” Surf 6,620’ 7” Tieback 26 L-80 Hyd 563 6.276” Surf 6,414’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 6,417’ 13,688’ TUBING DETAIL 2-7/8” Tubing 6.5 L-80 EUE 8rd 2.441” Surf 4,124’ 20” 9-5/8” shoe @ 6,620’ JEWELRY DETAIL No. Item Top MD ID 1 Tubing Hanger 33’ 2 GLM #2 - 2-7/8” x 1” w/ 1" DPSOV BK Latch 164’ 2.441 3 Stage Tool – ES Cementer 2,351’ 8.618” 4 GLM #1 - 2-7/8” x 1” W/ 1" DUMMY BK Latch 3,886’ - 5 XN Nipple 2.313” /2.205” No-Go 3,977’ 2.205” 6 Discharge Head: Bolt On w/ Pressure Sub 4,030’ - 7 Pump #1: 400 SF1750/124S 4,033’ - 8 Pump #2: 400 SF1750/124S 4,054’ - 9 Gas Separator: TANDEM/400 SERIES 4,076’ - 10 Upper Tandem Seal: 400 SERIES BPBSL/SS 4,081’ - 11 Lower Tandem Seal: 400 SERIES LSBPB/SS 4,090’ - 12 Motor : 456 Series FMS2 180 HP/2952 V/43A 4,098’ - 13 Sensor w/ Centralizer: Gauge 177 C 6000 PSI 4,119’ - 14 Bullet Seal Tie Back 8.66’ in TBR 6,414’ 6.180” 15 Liner Top Packer 6,417’ 7.380” 5-1/2” shoe @ 13,688’ 1 2 3 4 6 PBTD =13,690’ MD / 4,177’ TVD TD = 13,690’ MD / 4,177’ TVD Max Deviation: 95º 5-1/2” LINER DETAIL Jts Top (MD) Btm (MD) Length SOLID 6,443’ 6,483’ 40’ SLOTTED 6,483’ 8,592’ 2,109’ SOLID 8,592’ 8,947’ 355’ SLOTTED 8,947’ 9,603’ 656’ SWELL PKR 9,603’ 9,615’ 12’ SOLID 9,615’ 10,217’ 602’ SWELL PKR 10,217’ 10,233’ 16’ SLOTTED 10,233’ 12,248’ 2,015’ SOLID 12,248’ 12,639’ 391’ SLOTTED 12,639’ 13,654’ 1,015’ Liner Slot Dimensions= 2.250” L x .125” W / 6.72” Sq/In of Inlet Area per Foot of Casing / 24 Slots Per Foot of Casing GENERAL WELL INFO API: 50-029-23551-00-00 Drilled, Cased and Completed by Doyon 14 - 9/17/2015 ESP Change-out by ASR #1 – 10/16/2016 ESP Change-out by ASR #1 – 7/19/2017 ESP Change-out by ASR #1 – 3/11/2019 Casing Replacement & ESP Swap by ASR#1 – 2/20/2023 7 8 10 9 12 13 11 Min ID = 2.205” 5 14 15 & This is a centralizer, not the tie-back seal. The tie- back seal is in red, below. -WCB Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 2/7/2023 2/20/2023 Function test on BOPE revealed HCR & Pipe ram hoses backwards from BOPE supplier. Bled off accumulator & swap hoses. Completed winterization of rig. Obtain shell test ensure BOPE fluid packed & purged of air. Test BOPE as per approved sundry. AOGCC state rep. witnessed testing. All tests performed at 250 psi low and 2500 psi high f/ 5/5 charted mins. Performed accumulator drawdown test. Comms down to rig watch system. Testing not completed until comms issues found. Damaged cabling from rig to server. Issues fixed. Flow test performed for rig watch alarms. Testing completed. Blow down lines & L/D testing equipment. P/U handling equipment for ESP completion. Open IA & monitor well. W/ wellhead rep. P/U tee bar. Pull CTS plug. Sting into BPV. Slight pressure observed, allowed to bleed off through retrieval tool. Pull BPV. Well on Vac Shut IA. P/U landing JT screw into hanger. BOLDS. Open IA & monitor well. Pull hanger to floor. P/U WT = 32k No drag observed. Pump 15 bbls down backside, no returns. Cut ESP & cap lines & secure. L/D hanger. Slowly Pull ESP to run ESP & cap line over sheave. Retrieve lines at ground level, Secure to respected spoolers. Cont. POOH. POOH w/ 2-7/8" EUE 6.5# L-80 ESP completion F/ 4,297' T/ 3,113'. No operations to report. 2/4/2022 - Saturday No operations to report. 2/7/2023 - Tuesday 2/5/2023 - Sunday No operations to report. 2/6/2023 - Monday 2/3/2022 - Friday No operations to report. 2/1/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/2/2022 - Thursday No operations to report. Pull BPV. Well on Vac Shut IA Cut ESP & cap lines & secure. L/D hanger Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 2/7/2023 2/20/2023 2/10/2022 - Friday Completed jacking out of hole 17 JTS total to 5,720' P/U WT = 136K. Cont. POOH on elevators W/ 7-5/8" 29.7# L-80 HYD 511 Tieback F/ 5,720 ' T/ 3809' P/U WT = 98k. Pump pipe displacement every 3 JTs. Cont. POOH on elevators W/ 7-5/8" 29.7# L-80 HYD 511 Tieback F/ 3,809 ' T/ 814' P/U WT = 32k. Pump pipe displacement every 3 JTs. Service Rig, perform equip. fluid checks. Cont. POOH on elevators W/ 7-5/8" 29.7# L-80 HYD 511 Tieback. F/ 834 ' T/ 732' P/U WT = 30k. JT # 52 - 30 on tally have varying holes in casing. JT # 141 out - packed off w/ sand. Casing coming out completely packed off w/ sand. Mitigate sand with cuttings box below skate. Attempt to clear sand & L/D JTs. Recovered clamp pin in sand. 2/8/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary POOH w/ 2-7/8" EUE 6.5# L-80 ESP completion F/ 3,113' T/ 144'. L/D ESP completion as per ESP rep. Clamps recovered as follows: Canon clamp = 76, half clamp = 8, pump clamp = 6 (missing one clamp to OG tally), Protectalizer = 3, Flat guard = 2, missing 3 clamp pins. Clean & clear floor of ESP equipment. Extended clean up due to packed off between discharge head & pump. Remove sheave from derrick & ESP hose. Clear floor of tubing equipment. Remove rig tongs off hyd tong lift. Open IA & monitor well. Close blinds & change upper VBR rams to 7-5/8" solid body. Open blinds. Set test plug & back off running jt. Fill stack, & P/U 7-5/8" donut test JT. Place test JT & pull into upper rams. Close rams fully. Prep to test. Service rig, perform fluid checks on Equip. Test 7-5/8" solid body rams T/ 250 psi low & 2,500 psi high F 5/5 charted mins (good test). Rig dw testing equipment. Blow down all lines. With crane support. remove BOPE flow spools, install casing jacks & torque up. R/U casing equip. Function test casing jacks. 2/9/2022 - Thursday Cont. to rig up casing jacks. Change bails for height clearance. Pull handrail on carriage. Change elevator inserts. Load landing JT & pack off pulling tool P/U & M/U same. Check OA for pressure, 0 psi. Mobilize XO for landing JT. Finishing rigging up casing tongs & function test. Stage safety valves on floor. M/U to wellhead casing packoff BOLDS. Pull packoff, Free at 12k. L/D packoff & running tool. P/U & M/U landing JT to casing hanger. Pull 7-5/8" tieback string to 180k working up t/ 220k String not free. Cont. to work pipe. Slips at casing jacks caused indention in pipe. Call out for 175 ton "spiders". Cont. to work pipe. Shut bag, pump to wash around seals Pump down OA, 14 bbls to fill Pump at 2 BPM w/ 300 psi. Cont. to work pipe up to 200k. With crane support, fly to rig floor. 175K casing air slips "spiders". W/ casing jacks pull 7-5/8" tieback string to 220k, working up t/ 255k W/ casing jacks in tension at 255k set for 10 mins. P/U string free at 200k falling off to 180k Matching historic P/U WT. With crane support, remove from rig floor. 175K casing air slips "spiders". Jack 7-5/8" 29.7# L-80 HYD 511 Tieback OUT F/ 6417' T/ 5,720'. P/U WT = 129k Pump pipe displacement every 3 JTs. Continue L/d 7-5/8" 29.7# L-80 Csg and Seal Assembly. Total of 157 joints L/d. No sand of debris recovered after Jt 142. Cleared rig floor, L/d Packer Csg Handling eq. R/u crane, N/d Csg Jack and adapter plate. N/u flow and riser spool. R/u 3-1/2" handling eq. Changed out 7-5/8" ram with 2-7/8"x5" VBR's. R/u Testing eq. P/t rams w/3-1/2" test jt 250-2500psi and charted for 5mins-good test. R/d Testing eq. Built pit 1,2,and 3 to 45 vis. Racked and Tally 3-1/2" WS. R/u return line from C14 to shaker. M/u Cleanout BHA as following: 6" rev out bit & sub, 2ea 4-1/8" OD string magnet, XO sub/ 7-7/8" Csg scraper, 3-1/2" Pup jt, 4-3/4" Bumper Sub, 4-3/4" Hyd Jar, OX sub. RIH w/cleanout BHA p/u 3-1/2" NC31 WS f/surface t/3257' at report time. Fill hole w/2.5bbls of 8.4ppg SW every 15jts ran in hole. 2/11/2022 - Saturday Cont. POOH on elevators W/ 7-5/8" 29.7# L-80 HYD 511 Tieback F/ 3,809 ' T/ 814' M/U to wellhead casing packoff BOLDS. Pull packoff, Free at 12k. L/D packoff & running tool. P/U & M/U landing JT to casing hanger. Pull 7-5/8" tieback string to 180k working up t/ 220k String not free. Cont. to work pipe. Slips at casing jacks caused indention in pipe. Call out for 175 ton "spiders". Cont. to work pipe. Cont. POOH on elevators W/ 7-5/8" 29.7# L-80 HYD 511 Tieback. F/ 834 ' T/ 732' POOH w/ 2-7/8" EUE 6.5# L-80 ESP completion F/ 3,113' T/ 144'. L/D ESP completion as per ESP rep. Continue L/d 7-5/8" 29.7# L-80 Csg and Seal Assembly. Total of 157 joints L/d. Jack 7-5/8" 29.7# L-80 HYD 511 Tieback OUT F/ 6417' T/ 5,720'. POOH on elevators W/ 7-5/8" 29.7# L-80 HYD 511 Tieback F/ 5,720 ' T/ 3809' Completed jacking out of hole 17 JTS total to 5,720' Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 2/7/2023 2/20/2023 Hilcorp Alaska, LLC Weekly Operations Summary Continued KIH pumping down the Work-string, washing thru sand @ 2bpm/75psi with no returns f/5615' t/6250', PUW 62k/SOW=31k. Established full returns at shaker after 640bbls pumped. Monitored returns all. crude. Continued working pipe and washing down @ 3bpm/75-375psi w/1-3k WOB t/6290'. Transfer 240 oil from pits to tiger tank, call out vac truck to haul returns. Swapped line up and began rev circulating, KIH 2.5bpm/75psi began rotating pipe 25 RPM's, lost returns. Observed increase WOB attempt to washdown no joy, Made pickup f/6290' t/6171'. Attempt to pump down drill string and pressure increased, tried pumping both direction and determined power swivel and Derrick valves froze up. Worked on thawing out valves and lines. Attempt to move pipe with 50k over pull, seen bumper sub travel and jars hit-no movement. Secured well, Called out LRS to help with pumping while thawing lines. Note: High winds causing Phase 2 conditions in Milne. MIRU LRS, lineup to pump down 9-5/8", PT lines t/2700psi, Built 20 bbl Hi-vis sweep in pit 1. With DP Shut-in, LRS pumped 20bbl Hi-vis sweep down OA @ 2.25bpm/0psi followed 420bbls (Hole Vol) of 8.4ppg SW @ 5bpm/60psi. Seen pump pressure increase t/100psi when sweep hit BHA. SD pump, monitored well OA/DP on Vacuum. Picked up on work-string w/elevators and pipe was free, PUW=60k/SOW=30k. Crew change PJSM, check fluids serviced rig. Continued working on thawing eq. and winterizing cold spots as needed. Lost PTO on the Rig called out Mechanic to repair. Replaced leaking centrifugal pump in pits. Continued Test BOPE as per Sundry as Following w/3-1/2" TJ: Annular 250-2500psi, Rams 250-2500psi, Valves 250-2500psi and performed Koomey drawdown test. No failures recorded. No test on Gas detection last test was 2-7-23. Blow lines dry. Rd testing eq. C/o handling eq. to P/u BHA. Rack and Tally 3-1/2" WS. M/u Cleanout BHA as following: 6" rev out bit & sub, 2ea 4- 1/8" OD string magnet, XO sub/ 7-7/8" Csg scraper, 3-1/2" Pup jt, 4-3/4" Bumper Sub, 4-3/4" Hyd Jar, OX sub. RIH w/cleanout BHA p/u 3-1/2" NC31 WS f/surface t/3257'. C/o elevators and P/u 9 4-1/4" Drill Collars. Fill hole w/2.5bbls of 8.4ppg SW every 15jts ran in hole. Continued RIH and tag fill @ 5318' w/2k WOB (25' in Jt 134), PUW=52k, SOW=32k. K/u on Jt 143, lined up to pump long way. Began pumping 2bpm/70psi with no returns, KIH and washed/reamed f/5318' t/5615' @ report time. 2/14/2023 - Tuesday 2/12/2023 - Sunday Continued RIH w/cleanout BHA p/u 3-1/2" NC31 WS f/3257'. C/o elevators and P/u 9 4-1/4" Drill Collars. C/o elevators and Cont RIH w/3-1/2 WS f/4052' and tagged fill @ 5306'dpm. PUW=54k/SOW=31k. K/u on joint #134 and prepared to wash fill. PJSM and Crew change, service and inspect rig. Began pumping reverse @ 3.5bpm/0psi, pumped away 55bbl could not establish circulation. Swapped lineup to pump conventional, KIH washing/reaming down t/5,333', 30rpm/Tq on 1800ft/lbs. Rot Wt 42k. P/u jt #135 KIH and pump pressure increased to 1600psi. Shut pump, found drift plug was not removed from string and pumped down hole. R/d Kelly. POOH L/d 3-1/2 WS f/5,333' t/BHA, string pulling wet utilizing mud bucket to contain fluid from WS. Fill hole w/2.5bbls of 8.4ppg SW every 15jts out of the hole. L/d Cleanout assembly, recovered drift plug from BHA XO sub. Pumped 20bbls of 8.4ppg SW. Clean and cleared rig floor, serviced rig and eq. P/u BOP Testing eq. Prep for weekly BOP test. Flooded stack purge air out of system.Chased several leak during test and Perform shell test 250-2500psi- good test. Preforming weekly BOP test at report time. AOGCC witness was waived. 2/13/2023 - Monday M/u Cleanout BHA as following Continued RIH and tag fill @ 5318' w/2k WOB (25' in Jt 134), PUW=52k, SOW=32k. K/u on Jt 143, lined up to pump long way. Began pumping 2bpm/70psi with no returns, KIH and washed/reamed f/5318' t/5615' @ report time. Continued RIH w/cleanout BHA L/d Cleanout assembly Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 2/7/2023 2/20/2023 2/17/2022 - Friday Pulled seals free from PBR w/30k over pull on string, after seals pulled free PUW=53k SOW=28k. POOH L/d 3-1/2" WS f/6403'md t/BHA, maintaining 10bph hole fill with 8.4ppg SW. No issued POOH. C/o handling tools, L/d Bumper, Hyd Jars and Bullet Seal Assembly. Sent assembly to YJ to break out. Cleaned and cleared rig floor, cleaned pipe skate. Moved out pipe racks. Installed 7" pipe rams. Built 7" test joint and test plug, C/o elevators to P/u test joint. Landed 7" test joint. R/u testing equipment, filled stack and tested 7" pipe rams 250/2500psi, charted for 5mins good test, L/d test jt and testing eq. Blew down lines. 10bph hole fill with 8.4ppg SW. Discounted Hyd tongs and rack, N/d Bird Bath and Riser Spools, cleaned spools and tongs prep to pick with crane. 10bph hole fill with 8.4ppg SW. MIRU crane, fly off Hyd Rig Tongs, Bird Bath and Riser Spools, Fly up Csg Jacks, 350Ton Spiders, Parker Csg Tongs and Handling eq. R/u Jacks and Parker's Csg Handling eq. Spot in pipe racks. Racked and tally first row on 7" 26 #L-80 HYD 563 Casing. 10bph hole fill with 8.4ppg SW. 2/15/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Crew continued working on thawing out equipment and winterizing cold spots as needed. K/u and washed down f/6175' t/TOL @ 6417' fluffing sand with rig pump down DP @ 2-3bpm/0psi, and between DP connections stuffing sand away down the OA with LRS @ 5bpm/60psi. Washed 20' into PBR and set down 5k on TOL. Picked 10' and parked string. Shut-in DP, Mix and pumped 45bbl Hi-vis sweep with LRS down OA followed by 405bbls of 8.4ppg SW, Shut down pump, monitored well on vacuum. POOH on elevators L/d 2jts f/6427' t/6374', blew lines and prep to trip work-string. RDMO LRS. POOH w/Cleanout Assembly L/d 3-1/2" WS f/6417' t/BHA, tripped slowly off bottom until above the curve to ensure no sand was swapped back into casing, pumped dbl displacement every 15jts out (2.5bbls) w/8.4ppg SW. Observed 5-15k overpulls ~5894', ~5814' and ~5734'. Current depth is 1200. 2/16/2022 - Thursday Continued, POOH w/Cleanout Assembly L/d 3-1/2" WS f/1200 t/BHA, pumped double displacement every 15jt. L/d Jars, Magnets, Scraper and Bit. Visually inspect tools good. Clean and clear rig floor, visually inspect Derrick (no sign of damage on mast or carriage). repaired senor on rig motor. M/u bullet seal, 9-5/8" test packer, bumper and hyd jars. RIH w/Bullet Seal and Packer Assembly f/surface, set down @ 1166' (28' in on #28), K/u turned string 1/4 turns at time making attempts to work through tight spot w/ no joy. POOH L/d and inspected assembly-found rub marks on the bottom of the test packer (possible over torque collar or slightly collapses casing, pictures in folder) . No damage found on Bullet Seal Assembly. Sent assembly to Doyon 14 to breakout 9-5/8" test packer. M/u Bullet Seal Assembly, 3-1/2", OX Sub, 3-1/2" Pup jt, 4-3/4" Bumper Sub, 4-3/4" Hyd Jar, OX sub. RIH w/Seal Assembly P/u 3-1/2" WS f/surface, tag TOL @ 6403'DPM, PUW=59k SOW=28k locate and sting in seal assembly w/no issues. Set 7k down on no-go. R/u testing eq. Lined up to fill OA w/8.4 SW. Pumped 40bbls to fill OA. MIT- OA t/1500psi and charted for 15mins good test. Bleed off pressure and blew lines dry. Prep to POOH at report time. Pulled seals free from PBR Built 7" test joint and test plug, C/o elevators to P/u test joint. Landed 7" test joint. R/u testing equipment, filled stack and tested 7" pipe rams 250/2500psi, charted for 5mins good test, L/d test jt Racked and tally first row on 7" 26 #L-80 HYD 563 Casing POOH L/d 3-1/2" WS f/6403'md t/BHA, Lined up to fill OA w/8.4 SW. Pumped 40bbls to fill OA. MIT- OA t/1500psi and charted for 15mins good test Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 2/7/2023 2/20/2023 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. M/u 7" Bullet Seal Assembly Pup and XO Sub, RIH w/7" 26# L-80 563 HYD Csg f/surface t/4371'. PUW=52k SOW=46k. Maintained 10bph hole w/8.4ppg SW. Crew changeout, checked fluids on Rig and Eq. Continued RIH w/7" 26# L-80 563 HYD Csg f/surface f/4371' t/6370'. PUW=128k SOW=71k. Maintained 10bph hole w/8.4ppg SW. R/u work plate and 350ton Spiders, RIH located TOL on Joint #156 PUW=130k SOW=73k, stung in Seals and set 10k down on no-go. Marked for space out. L/d 3 joints, Calculated and M/u 7" space out pups. 9', 2',1', and 6' pups. PJSM, Crew change check fluids on rig and eq. P/u joint # 154, M/u OX sub, 7-5/8" Landing Jt w/safety valve and Csg Hanger. R/d 350 ton spiders. RIH w/hanger 10' above. MIRU LRS to OA, PT line to 2000psi, Spot Vac trucks, Closed Bag and Pumped 170bbls of 1% KCL w/corrosion inhibitor followed by 70bbls of diesel down OA @ 5bpm/100psi. SD pump. Landed Hanger w/62k down, B/o Landing jt. M/u pack-off running tool, Installed pack-off, L/d Landing Jt. Energized Pack-off 250/5000psi-good test. Pressure Test OA t/1000psi-good test. 2/18/2022 - Saturday Continued RIH w/Completion per design, f/2000' t/Hanger depth @ 4124', P/u 2-7/8" 6.5 L-80 EUE 8rd Tbg, utilizing x-collar clamps every other joint. Checking Electrical Connection every 1000'. Maintained 20bph Hole fill. PUW=34K, SOW=20k, P/u Tbg Hanger w/BPV Installed and Landing Jt, cut cable and control line. Summit preformed Penetrator Splice, Terminated cable and 3/8" cap line to Hanger. Hooked up Umbillical Cord to Penetrator and Landed Completion w/20k down on Hanger. Final surface check on cable good. RILDS. End of ESP assembly @ 4124'. 2/21/2023 - Tuesday 2/19/2023 - Sunday Clean rig floor, R/u crane, R/d and flyoff Packer Csg eq, Jacks and Mounting Plate, and 350ton Spiders. Fly up and R/u Riser Spool, Flow Spool, Tongs and Rack, Hyd Elevators. Installed Bird Bath. R/d Crane. Broke Ram door removed 7" rams and installed 2-7/8"x5" VBR's. Built 2-7/8" TJ, R/u Testing eq. Tested 2-7/8" Jt 250/2500psi, charted 5mins-good test. L/d Testing eq. Spotted Spooler Unit, Run Ropes thru and Hung Cable Sheave, Rack and Tally first row of 2-7/8" 6.5# L-80 EUE 8rd Tbg. First 61 joint ran in hole will be new Tbg. PU/Mu and Service New Summit ESP Assembly. Final surface checks good. RIH w/ESP Completion per design, picking up 2-7/8" 6.5# L-80 EUE 8rd Tbg. Spooling and cable and 3/8" cap line f/surface t/2000'. Utilized X-Collar Clamps on the first 10jts then every other joint thereafter. Check Electrical Connection @ 1000'. Maintained 10bph hole fill. 2/20/2023 - Monday Continued RIH w/Completion per design, f/2000' t/Hanger depth @ 4124', P/u 2-7/8" 6.5 L-80 EUE 8rd Tbg, utilizing x-collar clamps every other joint. Checking Electrical Connection every 1000'. Maintained 20bph Hole fill. PUW=34K, SOW=20k, P/u Tbg Hanger w/BPV Installed and Landing Jt, cut cable and control line. Summit preformed Penetrator Splice, Terminated cable and 3/8" cap line to Hanger. Hooked up Umbillical Cord to Penetrator and Landed Completion w/20k down on Hanger. Final surface check on cable good. RILDS. End of ESP assembly @ 4124'. M/u 7" Bullet Seal Assembly Pup and XO Sub, RIH w/7" 26# L-80 563 HYD Csg f/surface t/4371'. Rack and Tally first row of 2-7/8" 6.5# L-80 EUE 8rd Tbg. First 61 joint ran in hole will be new Tbg. PU/Mu and Service New Summit ESP Assembly. Final surface checks good. RIH w/ESP Completion per design, picking up 2-7/8" 6.5# L-80 EUE 8rd Tbg. Spooling and cable and 3/8" cap line f/surface t/2000'. Utilized X-Collar Clamps on the first 10jts then every other joint thereafte Continued RIH w/7" 26# L-80 563 HYD Csg f/surface f/4371' t/6370'. PUW=128k SOW=71k. Maintained 10bph hole w/8.4ppg SW. R/u work plate and 350ton Spiders, RIH located TOL on Joint #156 PUW=130k SOW=73k, stung in Seals and set 10k down on no-go. Marked for space out. L/d 3 joints, Calculated and M/u 7" space out pups. 9', 2',1', and 6' pups. PJSM, Crew change check fluids on rig and eq. P/u joint # 154, M/u OX sub, 7-5/8" Landing Jt w/safety valve and Csg Hanger. R/d 350 ton spiders. RIH w/hanger 10' above. MIRU LRS to OA, PT line to 2000psi, Spot Vac trucks, Closed Bag and Pumped 170bbls of 1% KCL w/corrosion inhibitor followed by 70bbls of diesel down OA @ 5bpm/100psi. SD pump. Landed Hanger w/62k down 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Casing Replacement Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,690'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 4,790psi Liner 6,390psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY twellman@hilcorp.com 777-8449 Taylor Wellman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0025515 & ADL0315848 215-118 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23551-00-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.05 MILNE PT UNIT L-46 Length Size Proposed Pools: 80' 80' TVD Burst PRESENT WELL CONDITION SUMMARY 4,177' 13,690' 4,177' 869 N/A 80' 20" MILNE POINT MD N/A 7,740psi 5,750psi 6,890psi 4,174' 4,156' 4,177' 6,620' 6,423' 13,688' 6,620' 6,423' Perforation Depth MD (ft): 5-1/2"7,271' Perforation Depth TVD (ft): Tubing Size: 9-5/8" 7-5/8" Tubing Grade: Tubing MD (ft): 6.5# / L-80 4,298' 1/8/2023 Liner Top Packer, Swell Packers (x2) and N/A 9,603' MD/4,168' TVD, 10,217' MD/4,196' TVD and N/A See Schematic See Schematic 2-7/8" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 12:47 pm, Dec 15, 2022 322-705 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.12.15 07:48:30 -09'00' David Haakinson (3533) BOPE test to 2500 psi. X 869 DSR-12/15/22MGR21DEC22DLB 12/15/2022 10-404 GCW 12/21/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.21 10:41:55 -09'00' RBDMS JSB 122222 ESP Swap / Casing Replacement Well: MPU L-46 Date: 12/14/2022 Well Name:MPU L-46 API Number:50-029-23551-00-00 Current Status:Oil Well [Failed ESP]Pad:L-Pad Estimated Start Date:January 8th, 2023 Rig:ASR Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:215-118 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 Second Call Engineer:Brian Glasheen (907) 564-5277 (O) (907) 545-1144 Current Bottom Hole Pressure: 1,270 psi @ 4,100’ TVD (BHP taken from L-48 on 6/2/22 / 6.0 ppg EMW) Maximum Expected BHP:1,270 psi @ 4,100’ TVD (BHP taken from L-48 on 6/2/22 / 6.0 ppg EMW) MPSP:869 psi (0.1 psi/ft gradient to surface) Brief Well Summary: MPU L-46 was drilled and completed in September 2015 as a horizontal Schrader Bluff ESP producer completed with slotted liner. ESP history: September 2015 (initial install), October 2016 and March 2019. In September 2019 the 7-5/8” casing developed a hole(s) and integrity was lost. Approval to continue to produce was granted via OTH-19-031 until the next time the ESP failed. The ESP has failed electrically and is grounded downhole. The recent success of pulling and replacing the 7-5/8” casing with 7” casing vs. installing a casing patch on MPU F-107 (PTD 218-001) and L-47 (PTD 215-117) is the driver for the revision to the procedure. Steps relating to the 7-5/8” casing patch have been removed. Notes Regarding Wellbore Condition x Confirmed hole(s) in 7-5/8” casing between 4,200’ – 4,500’md. The 7-5/8” x 9-5/8” annulus failed on 09/21/2019 with a leak rate of 2 bpm at 140 psi. The well was allowed to operate under the conditions outlined in OTH-19-031 and was approved on 10/07/2019. o As per the conditions of OTH-19-031, the 7-5/8” casing will be restored as part of this workover. Objective: Pull failed ESP, set casing patch to restore integrity to 7-5/8” casing and run new 2-7/8” ESP completion. Slickline (Non-sundried steps) 1. RU Slickline unit and pressure test PCE to 250psi/1,500psi high. 2. Drift and tag with sampler bailer 3. Pull lower GLV from 4,027’md. 4. Pull LGLV and set DGLV in upper GLM at 131’md. 5. Caliper tubing for possible reuse. 6. RD SL unit. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. ,p 869 psi ESP Swap / Casing Replacement Well: MPU L-46 Date: 12/14/2022 3. RU Little Red Services. RU reverse out skid and 500bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water/source water down tubing, taking returns up the IA to 500bbl returns tank. 6. Swap to pumping down the IA while taking returns up the OA to the 500bbl return tank. Bullhead down the IA and/or OA to ensure produced water/source water is completely circulated. 7. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 8. RD Little Red Services and reverse out skid. 9. Set BPV. ND tree. NU BOPE. Brief RWO Procedure: 10. MIRU ASR, ancillary equipment and lines. 11. Check for pressure and if 0 psi. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water or source water. Set CTS Plug. 12. Test BOP to 250/2,500 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min. a. Notify the AOGCC 24 hours in advance of BOP test. b. Test upper 2-7/8” x 5” rams with the 2-7/8” test joint. c. Confirm test pressures with Approved Sundry. d. Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug. e. Once BOPE test is complete, send a copy of the test report (10-424 form) to AOGCC and town engineer. 13. Bleed any pressure off casing to the returns tank. Pull CTS plug and BPV. Kill well with produced water or source water as needed. 14. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2019 ESP swap was 28K lbs to free pipe. The current completion was landed with a slack off wt of 22k and no PUW was recorded. 15. Recover the tubing hanger. 16. POOH and lay down the 2-7/8” tubing. Number all joints. Tbg will be inspected and brought to inventory unless damage or other observations are seen while pulling. Lay down failed ESP. a. Pull out all visually bad joints and mark for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. c. Keep GLM’s and jewelry for cleaning and visual inspection to be put in inventory for later re-use. 3 Protectolizers 2 Flat Guards 7 Pump Clamps 8 1/2 clamps 76 Cross collar clamps 17. Change out handling equipment, install casing crew tongs, and upper rams for handling 7-5/8” casing. Assure no pressure under BPV. Lubricate plug if necessary. ESP Swap / Casing Replacement Well: MPU L-46 Date: 12/14/2022 18. Perform BOP test on the 7-5/8” pipe rams on 7-5/8” test joint to 500/2,500psi. 19. Install casing jacks on top of BOP stack and function test. 20. Utilize casing jacks to unseat and pull 7-5/8” casing. a. PU weight during the 2015 installation of the 7-5/8” casing was 180k lbs. S/O weight = 132k lbs. Note that this weight was with a full column of 8.9ppg brine. Nordic 3 block weights were unrecorded. b. Use casing jacks until comfortably under the pulling limitations of the ASR and swap over to using the ASR elevators. c. Inspect the 7” bullet seals on the bottom of the 7-5/” casing for potential use on the test packer run later. 21. Swap pipe rams to 2-7/8” x 5” rams and test 3 ½’’ test joint to 500/2,500psi. 22. MU Clean out assembly. a. Attempt to clean out via forward or reverse circulating to ±6,417’ MD. Low side fill may require washing the FCO assembly down. If returns are not obtainable, contact OE about rotating and reciprocating while pumping and pushing solids into the liner while at final depth. 23. PU 7” Bullet seal assembly with 9-5/8” test packer above and TIH to ±6,417’ MD. Sting bullet seals into SLZXP, load well and PT 9-5/8” casing to 1,500psi. a. PUH as needed to determine competent 9-5/8” casing depth. Contact OE to discuss depth of passing test. 24. Swap pipe rams to 7” rams and test 7’’ test joint to 500/2,500psi. 25. Run 7” casing w/ bullet seal assembly. Space out and PU to circulate in 1% KCl w/ corrosion inhibitor with a diesel freeze protect into the 7”x9-5/8” annulus. Land 7” casing and pressure test to 1,000psi. a. 2,100’ of diesel freeze protection: 60bbls b. 7”x9-5/8” annulus to 6,417’ md (subtract freeze protect): 122bbls 26. Swap pipe rams to 2-7/8” x 5” rams and test 2-7/8’’ test joint to 500/2,500psi. 27. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’ a. Base of ESP at ± 4,160’ MD a. Chemical injection diffuser along the centralizer. b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 2 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. Multiple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV h. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 28. Land tubing hanger (Caution not to Damage Cable or capillary tubing while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 29. Set BPV. 30. RDMO ASR. ESP Swap / Casing Replacement Well: MPU L-46 Date: 12/14/2022 Post-Rig Procedure: Well Support 1. RD mud boat. Move to next well location. 2. RU crane. ND BOPE. Set CTS plug. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS plug & BPV. 6. RD crane. Move 500bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to production. RU well house and flowlines for a Jet Pump completion. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic ___________________________________________________________________________________ Revised by DAH 9/26/2019 Milne Point Unit Well: MP L-46 PTD: 215-118 API: 50-029-23551-00-00 Last Completed: SCHEMATIC RKB: 27’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 78.6 A-53 Weld 19.25” Surf 80’ 9-5/8" Surf. Csg 40 L-80 TC II 8.835” Surf 6,620’ 7-5/8” Tieback 29.7 L-80 Vam SLIJ-II 6.820” Surf 6,423’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 6,417’ 13,688’ TUBING DETAIL 2-7/8” Tubing 6.5 L-80 EUE 8rd 2.441” Surf 4,298’ 20” 9-5/8” shoe @ 6,260’ JEWELRY DETAIL No. Item Top MD ID OD 1 Tubing Hanger 32’ 2 GLM #2 - 2-7/8” x 1” w/ DPSOV BK Latch 131’ N/A 2.875” 3 Stage Tool – ES Cementer 2,351’ 8.618” 9.625” 4 GLM #1 - 2-7/8” x 1” Side Pocket w/ Dummy BK Latch 4,027’ 2.441” 2.875” 5 XN Nipple 2.313” / 2.205” no-go 4,113’ 2.205” 2.875” 6 SS Discharge Head: FPDISX 4,163’ - 4.00” 7 Pump #1 - 62 flex 17.5 SXD H6 Monel Coated 4,164’ - 5.380” 8 Pump #2 - 134 flex 17.5 SXD H6 Monel Coated 4,184’ - 5.380” 9 SS Gas Separator - GRSFTX AR H6 4,194’ - 5.380” 10 SS Upper Tandem Seal - GSB3DB XUT FER HL SSCV 4,197’ - 5.130“ 11 SS Lower Tandem Seal - GSB3DB XLT FER HL SSCV 4,204’ - 5.130“ 12 SS Motor CL5 – XPX : 150Hp / 2,420V / 38Amp 4,211’ - 5.620” 13 Sensor - Pheonix XT150 4,228’ - 4.00” 14 Centralizer 4,231’ - 5.130“ 15 Centralizer – Bottom @ 4,298’ 4,296’ - 5.850” 16 7-5/8” Tam Port Collar 6,353’ 6.280” 17 Bullet seal Tie Back 8.66’ in TBR 6,414’ 6.180” 7.350” 18 Liner Top Packer 6,417’ 7.380” 8.300” 5-1/2” shoe @ 13,688’ 1 2 3 4 6 17 16 PBTD =13,690’ MD / 4,177’ TVD TD = 13,690’ MD / 4,177’ TVD Max Deviation: 94.89º 18 5-1/2” LINER DETAIL Jts Top (MD) Btm (MD) Length SOLID 6,443’ 6,483’ 40’ SLOTTED 6,483’ 8,592’ 2,109’ SOLID 8,592’ 8,947’ 355’ SLOTTED 8,947’ 9,603’ 656’ SWELL PKR 9,603’ 9,615’ 12’ SOLID 9,615’ 10,217’ 602’ SWELL PKR 10,217’ 10,233’ 16’ SLOTTED 10,233’ 12,248’ 2,015’ SOLID 12,248’ 12,639’ 391’ SLOTTED 12,639’ 13,654’ 1,015’ Liner Slot Dimensions= 2.250” L x .125” W / 6.72” Sq/In of Inlet Area per FT of Casing / 24 Slots Per Foot of Casing GENERAL WELL INFO API: 50-029-23551-00-00 Drilled, Cased and Completed by Doyon 14 - 9/17/2015 ESP Change-out by ASR #1 – 10/16/2016 ESP Change-out by ASR #1 – 7/19/2017 ESP Change-out by ASR #1 – 3/11/2019 7 8 10 9 12 13 15 11 Min ID = 2.205” @ 4,137’ 5 14 IAxOA Leak (4,200’- 4,500’ MD). AOGCC approval to produce to Oct. 2023 or ESP failure ___________________________________________________________________________________ Revised by TDF 12/13/2022 Milne Point Unit Well: MP L-46 PTD: 215-118 API: 50-029-23551-00-00 Last Completed: PROPOSED RKB: 27’ CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 20” Conductor 78.6 A-53 Weld 19.25” Surf 80’ 9-5/8" Surf. Csg 40 L-80 TC II 8.835” Surf 6,620’ 7” Tieback 26 L-80 BTC 6.276” Surf ±6,423’ 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892” 6,417’ 13,688’ TUBING DETAIL 2-7/8” Tubing 6.5 L-80 EUE 8rd 2.441” Surf 4,298’ 20” 9-5/8” shoe @ 6,620’ JEWELRY DETAIL No. Item Top MD ID 1 Tubing Hanger 32’ 2 GLM #2 - 2-7/8” x 1” ±131’ 3 Stage Tool – ES Cementer 2,351’ 8.618” 4 GLM #1 - 2-7/8” x 1” ±3,897’ 5 XN Nipple 2.313” / 2.205” No-Go ±3,983’ 6 SS Discharge Head ±4,033’ 7 Pump #1 ±4,034’ 8 Pump #2 ±4,054’ 9 Gas Separator ±4,064’ 10 Upper Tandem Seal ±4,067’ 11 Lower Tandem Seal ±4,074’ 12 Motor ±4,081’ 13 Sensor ±4,098’ 14 Centralizer #1 ±4,101’ 15 Bullet Seal Tie Back 8.66’ in TBR 6,414’ 6.180” 16 Liner Top Packer 6,417’ 7.380” 5-1/2” shoe @ 13,688’ 1 2 3 4 6 PBTD =13,690’ MD / 4,177’ TVD TD = 13,690’ MD / 4,177’ TVD Max Deviation: 95º 5-1/2” LINER DETAIL Jts Top (MD) Btm (MD) Length SOLID 6,443’ 6,483’ 40’ SLOTTED 6,483’ 8,592’ 2,109’ SOLID 8,592’ 8,947’ 355’ SLOTTED 8,947’ 9,603’ 656’ SWELL PKR 9,603’ 9,615’ 12’ SOLID 9,615’ 10,217’ 602’ SWELL PKR 10,217’ 10,233’ 16’ SLOTTED 10,233’ 12,248’ 2,015’ SOLID 12,248’ 12,639’ 391’ SLOTTED 12,639’ 13,654’ 1,015’ Liner Slot Dimensions= 2.250” L x .125” W / 6.72” Sq/In of Inlet Area per Foot of Casing / 24 Slots Per Foot of Casing GENERAL WELL INFO API: 50-029-23551-00-00 Drilled, Cased and Completed by Doyon 14 - 9/17/2015 ESP Change-out by ASR #1 – 10/16/2016 ESP Change-out by ASR #1 – 7/19/2017 ESP Change-out by ASR #1 – 3/11/2019 7 8 10 9 12 13 11 Min ID = 2.205” 5 14 15 & Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/3/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221003 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 501332053001 214070 8/10/2022 Halliburton CH PPROF BRU 222-34 502832018600 222039 9/15/2022 Halliburton CH RBT BRU 244-27 502832018500 222038 9/13/2022 Halliburton CH RBT END 1-45 500292199100 189124 8/11/2022 Halliburton CH PERF KBU 22-06Y 501332065000 215044 8/22/2022 Halliburton CH PPROF KBU 43-07Y 501332062500 214019 9/7/2022 Halliburton CH PPROF MPU C-24A 500292302001 209134 8/3/2022 Halliburton CH COILFLAG MPU L-46 500292355100 215118 9/10/2022 Halliburton CH MFC24 MPU S-34 500292317100 203130 9/3/2022 Halliburton CH MFC24 NS-10 500292298500 200182 8/18/2022 Halliburton CH WFL- TMD3D NS-32 500292317900 203158 8/17/2022 Halliburton CH WFL- TMD3D PBU 04-30 500292134500 185089 9/17/2022 Halliburton CH RMT3D PBU 05-24A 500292220401 204218 9/12/2022 Halliburton CH CAST PBU 11-16 500292158100 186078 9/10/2022 Halliburton CH PPROF PBU 11-27A 500292163801 222036 8/20/2022 Halliburton CH RBT PBU C-24B 500292081602 212063 8/16/2022 Halliburton CH PPROF PBU E-100A 500292281901 218157 9/20/2022 Halliburton CH LDL PBU S-106 500292299900 201012 9/12/2022 Halliburton CH RBT Please include current contact information if different from above. 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Z>ŝƚƚůĞZĞĚ^ĞƌǀŝĐĞƐĂŶĚƌĞǀĞƌƐĞŽƵƚƐŬŝĚ͘ ϵ͘ ^ĞƚWs͘EƚƌĞĞ͘EhKW͘ ƌŝĞĨZtKWƌŽĐĞĚƵƌĞ͗ ϭϬ͘ D/Zh^Z͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐ͘ ϭϭ͘ ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŝĨϬƉƐŝ͘/ĨŶĞĞĚĞĚ͕ďůĞĞĚŽĨĨĂŶǇƌĞƐŝĚƵĂůƉƌĞƐƐƵƌĞŽĨĨƚƵďŝŶŐĂŶĚĐĂƐŝŶŐ͘/Ĩ ŶĞĞĚĞĚ͕ŬŝůůǁĞůůǁͬƉƌŽĚƵĐĞĚǁĂƚĞƌŽƌƐŽƵƌĐĞǁĂƚĞƌ͘^Ğƚd^WůƵŐ͘ ϭϮ͘ dĞƐƚKWƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮ͕ϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ Ă͘ EŽƚŝĨǇƚŚĞK'ϮϰŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ď͘ dĞƐƚƵƉƉĞƌϮͲϳͬϴ͟ǆϱ͟ƌĂŵƐǁŝƚŚƚŚĞϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚĂŶĚϯЪ͛͛ƚĞƐƚũŽŝŶƚ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐǁŝƚŚƉƉƌŽǀĞĚ^ƵŶĚƌǇ͘ Ě͘ ŶƐƵƌĞƚŽŵŽŶŝƚŽƌƐŝĚĞŽƵƚůĞƚǀĂůǀĞƐĂŶĚĂŶŶƵůƵƐǀĂůǀĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƚŽĞŶƐƵƌĞ ŶŽƉƌĞƐƐƵƌĞŝƐƚƌĂƉƉĞĚƵŶĚĞƌŶĞĂƚŚƚĞƐƚƉůƵŐ͘ Ğ͘ KŶĐĞKWƚĞƐƚŝƐĐŽŵƉůĞƚĞ͕ƐĞŶĚĂĐŽƉǇŽĨƚŚĞƚĞƐƚƌĞƉŽƌƚ;ϭϬͲϰϮϰĨŽƌŵͿƚŽK' ĂŶĚƚŽǁŶĞŶŐŝŶĞĞƌ͘ ϭϯ͘ ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨĐĂƐŝŶŐƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘WƵůůd^ƉůƵŐĂŶĚWs͘<ŝůůǁĞůůǁŝƚŚƉƌŽĚƵĐĞĚ ǁĂƚĞƌŽƌƐŽƵƌĐĞǁĂƚĞƌĂƐŶĞĞĚĞĚ͘ ϭϰ͘ DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌĂŶĚWhŽŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ Ă͘ dŚĞWhǁĞŝŐŚƚĚƵƌŝŶŐƚŚĞϮϬϭϵ^WƐǁĂƉǁĂƐϮϴ<ůďƐƚŽĨƌĞĞƉŝƉĞ͘dŚĞĐƵƌƌĞŶƚĐŽŵƉůĞƚŝŽŶ ǁĂƐůĂŶĚĞĚǁŝƚŚĂƐůĂĐŬŽĨĨǁƚŽĨϮϮŬĂŶĚŶŽWhtǁĂƐƌĞĐŽƌĚĞĚ͘ ϭϱ͘ ZĞĐŽǀĞƌƚŚĞƚƵďŝŶŐŚĂŶŐĞƌ͘ ϭϲ͘ WKK,ĂŶĚůĂǇĚŽǁŶƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐ͘EƵŵďĞƌĂůůũŽŝŶƚƐ͘dďŐǁŝůůďĞŝŶƐƉĞĐƚĞĚĂŶĚďƌŽƵŐŚƚƚŽ ŝŶǀĞŶƚŽƌǇƵŶůĞƐƐĚĂŵĂŐĞŽƌŽƚŚĞƌŽďƐĞƌǀĂƚŝŽŶƐĂƌĞƐĞĞŶǁŚŝůĞƉƵůůŝŶŐ͘>ĂǇĚŽǁŶĨĂŝůĞĚ^W͘ Ă͘ WƵůůŽƵƚĂůůǀŝƐƵĂůůǇďĂĚũŽŝŶƚƐĂŶĚŵĂƌŬĨŽƌĚŝƐƉŽƐĂů͘ ď͘ >ŽŽŬĨŽƌŽǀĞƌͲƚŽƌƋƵĞĚĐŽŶŶĞĐƚŝŽŶƐĨƌŽŵƉƌĞǀŝŽƵƐƚƵďŝŶŐƌƵŶƐĂ ŶĚũƵŶŬƚŚĞŵ͘ Đ͘ <ĞĞƉ'>D͛ƐĂŶĚũĞǁĞůƌǇĨŽƌĐůĞĂŶŝŶŐĂŶĚǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶƚŽďĞƉƵƚŝŶŝŶǀĞŶƚŽƌǇĨŽƌůĂƚĞƌ ƌĞͲƵƐĞ͘ 3URWHFWROL]HUV )ODW*XDUGV 3XPS&ODPSV FODPSV &URVV FROODUFODPSV ϭϳ͘ DhůĞĂŶŽƵƚĂƐƐĞŵďůǇǁŝƚŚĐĂƐŝŶŐƐĐƌĂƉĞƌĂďŽǀĞ͘ Ă͘ Z/,ƚŽцϲ͕ϰϭϬ͛DƚŽĞŶƐƵƌĞŶĞǁĐŽŵƉůĞƚŝŽŶǁŝůůĚƌŝĨƚƚŽĚĞƐŝƌĞĚĚĞƉƚŚ͘ ď͘ ůĞĂŶŽƵƚǀŝĂƌĞǀĞƌƐĞĐŝƌĐƵůĂƚŝŶŐƚŽϲ͕ϰϭϬ͛D͘ &KHFNIRUSUHVVXUHXQGHU&76SOXJ$VVXUHQRULVNRISUHVVXUHUHOHDVHEHIRUH SXOOLQJ%39 ^W^ǁĂƉͬĂƐŝŶŐWĂƚĐŚtŽƌŬŽǀĞƌ tĞůů͗DWh>Ͳϰϲ ĂƚĞ͗ϬϲͬϬϵͬϮϬϮϮ ϭϴ͘ WhϳͲϱͬϴ͟ƚĞƐƚƉĂĐŬĞƌĂŶĚd/,ƚŽцϲ͕ϰϭϬ͛D͘>ŽĂĚǁĞůůĂŶĚWdϵͲϱͬϴ͟ĐĂƐŝŶŐƚŽϭ͕ϱϬϬƉƐŝ͘ Ă͘ ,ŽůĞ;ƐͿŝŶƚŚĞϳͲϱͬϴ͟ĐĂƐŝŶŐǁŝůůŚĂǀĞĚŝƌĞĐƚĐŽŵŵƵŶŝĐĂƚŝŽŶď ĞƚǁĞĞŶϳͲϱͬϴ͟ĂŶĚϵͲϱͬϴ͘͟ ϭϵ͘ WƵůůƵƉŚŽůĞĂŶĚWdϳͲϱͬϴ͟ĐĂƐŝŶŐƚŽϭ͕ϬϬϬƉƐŝƵŶƚŝůƉĂƐƐŝŶŐƚĞƐƚŝƐĂĐŚŝĞǀĞĚ͘ Ă͘ dĂƌŐĞƚĚĞƉƚŚĨŽƌĐŽŵƉůĞƚŝŽŶƉĂĐŬĞƌŝƐцϰ͕ϭϴϬ͛D͘ ď͘ ŽŶƚĂĐƚKǁŝƚŚůĞĂŬĚĞƉƚŚŽƌƉĂƐƐŝŶŐWdŽĨƚŚĞϳͲϱͬϴ͟ĐĂƐŝŶŐĚĞƉƚŚ͘ ϮϬ͘ WhůŽǁĞƌƉĂƚĐŚĂƐƐĞŵďůǇ;ϳ͟ǆϰͲϭͬϮ͟dƌŝƉŽŝŶƚWĂĐŬĞƌĂŶĚƚŝĞďĂĐŬͬƐŶĂƉůĂƚĐŚĂƐƐĞŵďůǇͿĂŶĚZ/,͘ ŽůŽƌƐŝŶĚŝĐĂƚĞĂƐƐĞŵďůŝĞƐƚŽďĞďƵĐŬĞĚƵƉƉƌŝŽƌƚŽZtK͘ 1RP 6L]H a/HQJWK ,WHP /EIW 0DWHULDO 1RWHV :/(*/ 3XS-RLQW / ;1LSSOH /&RQWLQJHQF\ IRU IXWXUH SUHVVXUH WHVWLQJ1RWQHHGHGWRVHWSDFNHU ;2/RFDWRU / [ 7ULSRLQW 3DFNHU /¶0' 6QDS/DWFK$VVHPEO\/ Ϯϭ͘ d/,ĂŶĚůĂŶĚƚŚĞŶŽͲŐŽĂƐƐĞŵďůǇŽŶƚŚĞϳ͟ůŝŶĞƌƚŝĞͲďĂĐŬĂƚцϲ͕ϰϮϬ͛D͘ ϮϮ͘ ƌŽƉďĂůůĂŶĚƐĞƚϳͲϱͬϴ͟ǆϰͲϭͬϮ͟dƌŝƉŽŝŶƚƉĂĐŬĞƌĂƐƉĞƌƐĞƚƚŝŶŐƉƌŽĐĞĚƵƌĞ͘ Ă͘ dŚĞƐĞƚƚŝŶŐƚŽŽůŚĂƐĂĐĂƚĐŚƚŚĂƚǁŝůůƐĞƚĂŶĚƌĞĐŽǀĞƌƚŚĞďĂůůǁŚĞŶƉƵůůĞĚ͘EŽƚĞƌĞĐŽǀĞƌǇŽĨ ďĂůůŝŶƌĞƉŽƌƚ͘ Ϯϯ͘ WƌĞƐƐƵƌĞƚĞƐƚƚŚĞďĂĐŬƐŝĚĞ;ǁŽƌŬƐƚƌŝŶŐǆϵͲϱͬϴ͟ĐĂƐŝŶŐƚŽϭ͕ϬϬϬƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐĐŚĂƌƚĞĚͿ͘ Ϯϰ͘ WhŶĞǁϯͲϭͬϮ͟ƉĂƚĐŚĂƐƐĞŵďůǇĂŶĚZ/,͘ ŽůŽƌƐŝŶĚŝĐĂƚĞĂƐƐĞŵďůŝĞƐƚŽďĞďƵĐŬĞĚƵƉƉƌŝŽƌƚŽZtK͘ 1RP 6L]H a/HQJWK ,WHP /EIW 0DWHULDO 1RWHV ´6QDSODWFK$VVHPEO\/,' ´ -RLQWV / 3XS-RLQW / ;1LSZLWK5+&SURILOH /6HWOHVVWKDQGHJUHHVa 0' 3XS-RLQW / MRLQW / ;2 WR -RLQW / ´´3DFNHU /7UL3RLQW3DFNHUVHW 0' 6HDOERUH $VVHPEO\ Z 6QDS/DWFK / 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ϭ͕Ϭϭϱ͛ >ŝŶĞƌ^ůŽƚŝŵĞŶƐŝŽŶƐсϮ͘ϮϱϬ͟>ǆ͘ϭϮϱ͟tͬϲ͘ϳϮ͟^Ƌͬ/ŶŽĨ/ŶůĞƚƌĞĂ ƉĞƌ&ŽŽƚŽĨĂƐŝŶŐͬϮϰ^ůŽƚƐWĞƌ&ŽŽƚŽĨĂƐŝŶŐ 'EZ>t>>/E&K W/͗ϱϬͲϬϮϵͲϮϯϱϱϭͲϬϬͲϬϬ ƌŝůůĞĚ͕ĂƐĞĚĂŶĚŽŵƉůĞƚĞĚďǇŽǇŽŶϭϰͲϵͬϭϳͬϮϬϭϱ ^WŚĂŶŐĞͲŽƵƚďǇ^ZηϭʹϭϬͬϭϲͬϮϬϭϲ ^WŚĂŶŐĞͲŽƵƚďǇ^ZηϭʹϳͬϭϵͬϮϬϭϳ ^WŚĂŶŐĞͲŽƵƚďǇ^ZηϭʹϯͬϭϭͬϮϬϭϵ ϳ ϴ ϭϬ ϵ ϭϮ ϭϯ ϭϲ͕ϭϳ ϭϭ DŝŶ/ сϮ͘ϮϬϱ͟ ϱ ϭϰ͕ϭϱ /ǆK>ĞĂŬ;ϰ͕ϮϬϬ͛Ͳ ϰ͕ϱϬϬ͛DͿ͘K' ĂƉƉƌŽǀĂůƚŽƉƌŽĚƵĐĞƚŽ KĐƚ͘ϮϬϮϯŽƌ^WĨĂŝůƵƌĞ Ϯϰ͕Ϯϱ ϭϴ ϮϬ Ϯϭ͕ϮϮ͕Ϯϯ ϭϵ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY October 2, 2019 David Haakinson Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov 'T -D ZI 5 ► l$"l Re: Docket Number:OTH-19-031 Request to Continue Production of MPU L-46 with IA by OA Communication Dear Mr. Haakinson: Your request to allow continued production on L-46 with a known IA b- OA leak is APPROVED. Since this is an ESP completion without a production packer, the well now has one barrier to flow (9 5/8" surface casing). Several mitigating factors are noted such as the well is new (drilled in 2015) with recently tested casing and a no -flow test indicating fluid rates are relatively low. To eliminate or greatly reduce the likelihood of external surface casing corrosion, Hilcorp Alaska, LLC has filled the 9 5/8" by conductor space with dielectric grease. The AOGCC will allow production to continue on L-46 conditionally as follows: I ) L-46 wellhead pressures (T/IA/OA) must be monitored daily. 2) The IAxOA leak must be repaired at the earliest RWO opportunity (ESP failure) or within 4 years of this approval. (At this point a RWO will be required to repair the IAxOA leak whether or not the ESP is still functioning.) 3) The well schematic will require the IAxOA leak noted as well as the 4 -year limit (October 2023) on continued production before requiring a RWO. Sincerely, / ssie L. Chmielowski Commissioner H Hilcoru Alaska, LLC September 26, 2019 Commissioner Jessie L. Chmielowski Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Re: Milne Point Production Well MPU L-46 (PTD # 2151180) Request To Continue Production of MPU L-46 with IA by OA Communication Dear Commissioner Chmielowski, Hilcorp Alaska, LLC (HAK) requests approval to continue to produce packer -less ESP well L-46 with an Inner Annulus by Outer Annulus leak. Schrader Bluff producer MPU L-46 exhibits Inner Annulus by Outer Annulus communication that is manageable by bleeds. A caliper survey was completed during the rig workover in March 2019, and indicated a leak below the ESP completion. A mechanical integrity test of the OA failed on 9/21/19 with an established leak rate of 2 BPM at 140 psig. With the production casing leak, the packer -less well equates to a mono -bore style ESP completion with a single barrier. While mono -bore ESPs are being phased out at Milne Point, existing mono -bore wells continue to be operated safely with regular pressure testing as per CO 390A. MPU L -46's 9-5/8" surface casing passed an integrity test to 3000 psi on 8/28/15 during the initial completion, and is documented to have cement to surface. To establish integrity of the 7-5/8" production casing, a rig workover will be necessary to pull the ESP completion and repair the production casing. HAK requests to produce the well until the next rig workover or within 4 years, whichever comes first. HAK projects an average ESP run -life of 12-18 months for L-46 based on three previous rig workovers. As with all in service Milne Point wells, MPU L -46's tubing, inner annulus, and outer annulus pressures are documented daily for trending of pressure data and detection of mechanical integrity issues. Page �2 HAK believes MPU L-46 is safe to operate as stated above and requests approval to continue to produce the well until ESP failure or change in the well's mechanical integrity, at which time the IAxOA leak will be repaired with a rig workover. If you have any additional questions concerning this request, please contact me at 777- 8343 or by email at dhaakinson@hilcorp.com. Sincerely, David Haakinson Operations Engineer Hilcorp Alaska, LLC Attachments: Technical Justification TIO Plot Wellbore Schematic 9-5/8" Surface Casing Test on 8/28/15 CC Guy Schwartz James Regg P:,�,c 13 Milne Point L-46 Technical Justification for Production Approval Request September 26, 2019 Well History and Status MPU L-46 was drilled and completed in the Schrader Bluff OA sand in September 2015. The well has been a problematic producer due to artificial lift difficulties. Rig workovers have been completed on the well three times due to two ESP failures, and one tubing leak. During the March 2019 rig workover to replace the tubing string, corrosion damage was found on most tubing joints. While the tubular completion was out of the hole, a caliper survey was completed on the 7-5/8" casing. After the survey was completed, the ESP completion with new tubulars were installed, prior to caliper data processing. After the rig workover was completed and caliper was processed, the log identified multiple holes in the 7-5/8" production casing below the ESP set depth from 4,200' to 4,500' MD. Informal discussions were had with AOGCC regarding continued production of the well until the next ESP change -out, but were not properly requested or documented by HAK. After the development of the MPU L-47 IAxOA communication in September 2019, the documentation error for MPU L-46 was found. In Hilcorp's well integrity database, the annular communication was documented as: "Confirmed IAxOA communication. AOGCC approval for continued operation until next RWO at which point production casing holes must be remediated" However, no written documentation of this approval is known. Due to this error, HAK requests official written approval to continue production. The producer remains online to date and has two OA bleed events in 2019. Repair Considerations A repair of the well's 7-5/8" casing would entail the shut-in and removal of an operable ESP. Due to the set depth and restriction of the ESP, further diagnostics of the leak location are not possible. After removal of the ESP completion, the 7-5/8" casing will likely be pulled and replaced due to the multiple holes found by means of the caliper survey conducted on 3/10/19. Barrier Evaluation The primary barrier envelope is the 9-5/8" surface casing that passed a pressure test to 3000 psig on 8/28/15. The surface casing was cemented to surface. The 40 Ib/ft L-80 casing was installed new in 2015, and with a burst rating of 5,750 psig can safely operate within our operational parameters of a MOASP of 1000 psig with assumptions of either a liquid or gas packed annulus. Due to the two stage cement job to surface and age of the completion, HAK views the risk of surface casing failure to be very low. Page 14 During the March 2019 rig workover, a new string of 6.5# L-80 tubing was installed in the well. Proposed Operating and Monitoring Plan 1) A no -flow test will be completed on MPU L-46 to test the producer's ability to flow to surface. 2) Record wellhead pressures daily 3) The well's OA MOASP is limited to 1000 psi. The well will be shut in if unable to maintain pressure below MOASP. 4) The well will be shut-in and the AOGCC notified if there is a change in the well's mechanical condition. AOGCC approval shall be required to restart production following any such shut-in. 1200 1000 800 -A 1 5 i Z OR 905 MPU L-46 180 -Day TIO Plot Tubing(psi) —IA(psi)—OA(psi) 0 0 u 3/1/2019 4/1/2019 9/1/2019 6/1/2019 7/1/2019 8/1/2019 9/1/2019 Explanation of Events: 1. 3/4/19: Well shut-in for tubing leak and subsequent RWO. 2. 8/6/19: Well shut-in for Milne Point facility maintenance. OA bleed. Min = 2.. @ RKe: 27' SCHEMATIC CASING DETAIL Milne Point Unit Well: MP L-46 PTD: 215-118 API: 50-029-23551-00-00 Last Completed: Size I Type I Wt I Grade I Conn. I ID I Top I Btm 80' 6,620' 6,423' L3,688' 4,298' PBTD -13,690' MD / 4,177' TVD TD = 13,690' MD / 4,177' TVD Max Deviation: 94.892 L I1rV API: 50-029-23551-00-00 Drilled, Cased and Completed by Doyon 14 - 9/17/2015 ESP Change -our by ASR #1-10/16/2016 ESP Change -out by ASR#1-7/19/2017 ESP Change -out by ASR #1— 3/11/2019 ID 75" 25" 75" 75" Kl" 80" 80" 80" 30" 30" 20" 10" 30" 50" 50" )0" 2" shoe @ .3,688' Revised by DAH 9/26/2019 RKS: 2T Page 16 Fkilne Fo nt Urit Well: NF L-46 PTD'. 255-118 SCHEMATIC CASING DETAIL Size I Type I ft( I Gmde I Cann. I IT I Top I 8tm 8Q' 5,62D' 5,423' 3,68&' t,292' PBTD c13,696 MD/4,177 TVD TO =13,690' WD 14;177' 7VD Max Deriatim: 94.891? API: S"294235514)OCa Drilled Cased and Crxn leted try l uoun 14 -9/17/1015 CSP Cha eaut NYASR R1-1Q71C42016 CSP Cha e-uul by ASR 81-7119 12417 CSP Cfianze O by ASR 01-3112419 z" shoe C 3.59_ P _c1� MPU L-46 9-5/8" Surface Casing Pressure Test Well Service Report well MPL-as Field MPU Data 9/28/2019 lob Scope No flow test WSM Linder Crew Supervisor I Well Support I Service Provider Daily Summary Perform passing No -Flaw test on tubing and IA. Max gas return rate was 8mcfg with less than one gallon return fluid during the 3hr test. Rigged down all equipment and returned well to production. STATUS WHIP IA Prod 1 300 320 OA 520 Operations Log TimeTBG IA OA cfg fluid rate max gas read Comments 13:30 300 320 520 duringtest Pad operator shutdown ESP 56Hz/21am /760 bh 13:35 300 320 520 oo�©oo� Using 2"hose, bled tubing and lA to flowback tank 15:00 0 0 560 0 0 Isolate 2" hose from tank, start flow through 1/2 meter 15:01 1 b.5 f 0 1 560 1 6.5 1 1 gal 1 6.5 1 1 Start 3 hour no flow test I Total Field Estimate 1257.001 rr oo�©oo� rr oo�®oo� •rr ---_---Returned FINALCONDITIONS STATUS WHIP 1A .. rr rrr :. rr rrr I Total Field Estimate 1257.001 Tnlcurn Alnrkn, LM DATE 07/18/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU L-46 PTD 215-118 CD 1: MultiFinger Caliper Log 05 Mar 2019 3 1 0 1 7 MultiFinger Caliper Log 10 Mar 2019 3 1 0 1 8 RECEIVE► JUL 19 2019 AOGCC 215118 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, March 21, 2019 1:09 PM To: Schwartz, Guy L (DOA)' Subject: RE: [EXTERNAL] L-46 ESP workover for tubing leaks (PTD 215-118)'! Guy, The casing caliper was a step we had discussed on the phone that this would be a good time for diagnostics (only time we could grab this data with the ESP out of the ground) but I failed to submit a notification of it being added. I ran the caliper on memory since there wasn't an indication of the casing being in this bad of condition and the well had a passing pressure test 3-1/2 years ago. The short version is that the casing looks bad in the area below where the tubing and ESP were sitting with holes indicated in the 7-5/8" casing. This further lends to the microbial corrosion mechanism that we believe to be happening. The question that comes into play is the path forward for this well. If you can call me at your convenience I would like to discuss this one further. Thanks, Taylor From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 20, 2019 8:56 AM To: Taylor Wellman <twellman@hilcorp.com> Subject: [EXTERNAL] L-46 ESP workover for tubing leaks (PTD 215-118) Taylor, What did the tubing look like when pulled on L-46? What about the caliper log for the casing? I didn't see this in the sundry. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDEN17ALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska�). STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR 19 2N9 1. Operations Abandon Lj Plug Perforations Ll Fracture Stimulat Pull Tubing d Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulat Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ =rforate New Pool ❑ Repair Wel❑ Re-enter Susp Well ❑ Other: ESP Workover 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development B Slratigraphic ❑ Exploratory ❑ Service ❑ 215-118 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23551-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0315848, ADL0025509 & ADL0025515 MILNE PT UNIT L-46 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 13,690 feet Plugs measured N/A feet true vertical 4,177 feet Junk measured N/A feet Effective Depth measured 13,690 feet Packer measured 6,417 feet true vertical 4,177 feel true vertical 4,157 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,589' 9-5/8" 6,620' 4,174' 5,750psi 3,090psi Production 6,386' 7-5/8" 6,423' 4,156' 6,890psi 4,790psi Liner 7,271' 5-1/2" 13,688' 4,177' 7,740psi 6,390psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / L-80 / 8rd EUE 4,298' 3,408' Packers and SSSV (type, measured and true vertical depth) Liner Top N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A r —ZO —� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 68 6 123 220 210 Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070.25.071,& 25.283) 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 Lj WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby Certify that the foregoing is true and Correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-103 Authorized Name: Chad Helgeson Contact Name: Taylor Wellman —.9pi Authorized Title: Operations Manager Contact Email: tweliman(a)hilcorp.com Authorized Signature: Date: 3/14/2019 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 5_'� , /'� 'sI; olue RB®MS( P- MAR 2 0 2019 Submit Original Only Mil =2 Milne Point Unit Well: MP L-46 PTD: 215-118 SCHEMATIC API: 50-029-23551-00-00 Ril.m A".. Lu: Last Completed: RKB: 27' CASING DETAII Size I_ Type I Wt I Grade I Conn. I ID I Top I Btm 80' 6,620' 6,423' L3,688' 4,298' PBTD =13,690' MD / 4,177' TV D TD = 13,690' MD / 4,177' TVD Max Deviation: 94.899 API: 50-029-23551-00-00 Drilled, Cased and Completed by Doyon 14 - 9/17/2015 ESP Change -out by ASR k1 —10/16/2016 ESP Change -out by ASR #1— 7/19/2017 ESP Change -out by ASR #1-3/11/2019 ID 75" 25" 75" 75" la' 80" 8a' 80" 30" 30" 20" 0„ 30" 50" i0" ]0" 2" shoe @ 3,688' Revised by TDF 3/14/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 3/8/19 3/11/19 Daily Operations. 3/6/2019 - Wednesday No activity to report. 3/7/2019 - Thursday No activity to report. 3/8/2019 - Friday Continue MIRU ASR and spotting equipment. Nipple up BOP- Function test BOP hydraulic control lines for Good Function test. Electricians connected and tested fire and gas alarms on ASR. Safety Personnel performed Safety Walk Down for tight working areas on location. Start Shell test shell test was bad found a leaking gland nut on the well head lock down pin. bleed down and tighten. Pressure back up on high. still leaking through gland nut. Call out Well head support to change out gland nut on well head. Started shell test again shell test failed. started to hunt for leak. Checked all surface equipment and lines for leaks could not see any leaks. From there picked up 2 7/8" with TIW and IBOP test sub to eliminate the blind rams, still seeing same trend with the pipe rams and bag. With no surface leaks and mud-X Blocked in to eliminate mud-X valves. This leads us to believe the blanking sub is leaking. called wellhead support to come out and put in two way check., Pull Blanking sub. fluid in the stack did not fall, indicating that the well has some pressure on it. Bleed off tbg and pull BPV. Put in TWC. Start shell repeat shell test - shell test good. 250psi low and 2,500psi high test for 5minutes , no leak-off. bleed off pressure and repeat shell test for positive verification. repeat test good 250 low and 2,500psi high for 5 minutes with no leak off. Bleed off pressure and proceed with BOP test. 3/9/2019-Saturday Crew swap out and proceed with BOP testing. Test BOP w/ 2-3/8" x 3-1/2" VBR's for 250psi low and 2,500psi high test for 5 minutes for Good test. Test all Valves on choke/kill manifold, blinds, and annular as per sundry to 250 low and 2,500psi high for 5 minutes all good test. Drawdown from 2,900psi to 1,800psi w/ 200psi recovery in 14 seconds with full recovery in 51 seconds. Complete BOP testing and blow down all lines. Repair link tilt on ASR rig, found loose wire preventing link tilt. Prep to pull 2way check, take on 200 bbls produced water, pull 2 way check and prep to pull hanger. BOLDSpull hanger P 28K up. Disconnect power cable and cap string - thread both to spooler. Lay down hanger and prep to POOH. POOH/w 2-7/8" 6.5# L-80 EUE TBG with 3/8" Cap. tube, #2 ESP cable and ESP. Lay down BHA except for the Motor and seals left them hanging upright in the derrick. RU Halliburton to run CSG log. Hold safety meeting with Halliburton, hold a table top well control drill with 3rd party. RIH with slick line and start CSG log from 4,520' to surface. (Daylight savings time move clock forward 1 hr.) load 120 bbls source water to pits AJ l— L di 3/10/2019-Sunday HES slickline and casing caliper log out of hole RDMO HES Slickline. Check all fluids in equipment, spot pipe racks, move in new tubing string and tally, prep to change out spools in spooling unit. P/U ESP lower centralizer, connect Cap string, 2 joints tubing and ESP Centralizer, P/U ESP motor and seals, drain and change oil, makeup ESP Assembly,. RIH 98 jnts 2-7/8" #6.5 EUE L-80 TBG testing ESP cable every 1,000' and cap tube every 2,000'. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 3/8/19 3/11/19 Daily Operations. 3/11/2019 - Monday Crew swap and check all fluids in equipment. Continue to RIH w/ 2-7/8" L-80 6.5# EUE tubing and ESP assembly, testing every 1,000' and cap string every 2,000'. Prep to P/U hanger, land hanger and terminate. P/U hanger, make power cable terminations and cap string terminations, land hanger w/ 22K down weight. Total clamps run 8: 1/2 clamps, 3: protectolizers, 2 flat guards, 7 pump clamps, 76 X -collar clamps. Lower ESP centralizer @ 4,297', XN nipple @ 4,114', Lower GLM w/ dummy valve @ 4,027', and upper GLm w/ DPSOV @ 131'. Hanger landed w/ 22K down, back out and lay down landing joint, install BPV, Tighten lock down screws, start RDMO ASR. RDMO ASR rig to A- Pad, ND BOPE, NU Production head. Test void 250psi low/ 5,000psi High. pull BPV. 3/12/2019 -Tuesday No activity to report. THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-46 Permit to Drill Number: 215-118 Sundry Number: 319-103 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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, �Danlel T. Seamount, Jr- XN— Commissioner DATED this -J!d-ay of March, 2019. "BO R06 , MAR 0 7 IM STATE OF ALASKA i ` 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS =,r 70 AA(' 95 9R0 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: ESP RWO ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q . Stratigraphic ❑ Service ❑ 215-118 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23551-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 - Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT L-46 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0315848: ADL0025509, ADLOO25515 MILNE POINT / SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,690' 4,177' 13,690' 4,177' 260 N/A WA Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,620' 9-5/8" 6,620' 4,174' 5,750psi 3,090psi Production 6,423' 7-5/8" 6,423' 4,156' 6,890psi 4,790psi Liner 7,271' 5-1/2" 1 13,688' 14,177' 7,740psi 6,390psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5# / L-80 / EUE 8rd 4,312' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Liner Top and N/A 6,417 MD/ 4,157 TVD and N/A 12. Attachments: Proposal Summary 4 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: 3/8/2019 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman Tr.../ Authorized Title: Operations Manager Contact Email: twelinnanicDhilcorp.com Contact Phone: 777-8449 Authorized Signature: Date: 3/5/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 G-10� Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ElLocation Clearance ❑ Other: Y25o0 los.: 6610 C,� r Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No (3/ Subsequent Form Required: f ©-� 7 (, Ll yt` APPROVED BY I Approved b "' UI C MMISSIONER THE COMMISSION Date: 7 I ORIGINAL RBUMSI:�" MAR 0 7 201% ubmft Form and /�/ Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments m Duplicate i U Hilwrp Alaska, LD ESP Change -Out Well: MPU L-46 Date: 03/04/2019 Well Name: MPU L-46 API Number: 50-029-23551-00 Current Status: Shut in - ESP not surfacing fluids Pad: L -Pad Estimated Start Date: March 08, 2019 Rig: ASR 1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 215-118 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907)777- 907)777- (0) (907)331-8228 (M) IAFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,235 psi @ 3,337' TVDss BHP after 2 day SI — Mar 2019 / 7.2 ppg EMW Maximum Expected BHP: 1,235 psi @ 3,337' TVDss BHP after 2 day SI — Mar 2019 / 7.2 ppg EMW MPSP: 260 psi ✓ (Maximum IA Pressure recorded on 09/16/18) Brief Well Summary: MPU L-46 was drilled and completed in September 2015 as a horizontal Schrader Bluff ESP producer completed with slotted liner. ESP history: September 2015 (initial install), October 2016 and July 2017. In June 2018 the well stopped lifting fluids and slickline diagnostics found a hole in the 2-7/8" tubing. Prior to the 2017 RWO, a tubing caliper was run which indicated tbg penetrations up to 60%. Indications are that this tubing was re -run during the RWO. There is a high likelihood of multiple tubing leaks. Recently the well was showing declining performance and the Hz/Amps were increased to maintain total fluid rates. The ESP was shut down yesterday due to overheating and high Amp spikes. -- Notes Regarding Wellbore Condition • High probability of multiple tubing leaks. A 7/3/2018 caliper showed 24 joints with 40-85% wall penetrations. • 9-5/8" x 7-5/8" casing annulus tested to 1,000 psi for 30 minutes 09/15/2015. Objective: Pull the ESP completion and run anew tubing string with ESP completion. Pre -Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. hVl� J(/ 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing, taking returns up casing to 500 bbl returns tank. 1� 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. NO Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. U Hile ,p Alaska, 1.1.E Brief RWO Procedure: ESP Change -Out Well: MPU L-46 Date: 03/04/2019 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 p ram/valve and test accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2017 ESP running was 86K lbs / SOF = 25K lbs. b. If needed, circulate (long or reverse) pill with lubricant and/or baraclean pill prior to laying V 7 down the tubing hanger. During the 2017 RWO, this circulation greatly aided tubular cleaning of a thicker crude. 16. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Take all tubing to G&I for washing and disposal. Lay down ESP. a. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over -torqued connections from previous tubing runs. c. The completion has the following amount of clamps/guards: i. 5 Protectolizers H Mears Alaska. LU ii. 2 Flat Guards ESP Change -Out Well: MPU L-46 Date: 03/04/2019 iii. 193 Crosscollar Clamps 18. Contingency - Inspect ESP pumps and motor. If pumps and/or motor show any indication of fill/corrosion damage or any other issue that would warrant further review and not re -running, contact OE and run 2-7/8" kill string to 3000' md. Proceed with step 20. 19. PU ESP (reuse motor & pump sections w/ new seals) with single cap string and RIH on 2-7/8" tubing. Set base of ESP assembly at ± 4,246' MD. a. Upper GLM @±140'MDw/SO b. 2-7/8" tubing c. Lower GLM w/ DGLV d. 3 joints of 2-7/8" tubing e. 2-7/8" XN (2.205" No -Go) f. 1 joint of 2-7/8" tubing g. Downhole gauge for discharge temperature and pressure (connected with a jumper from the lower sensor. Does not require a separate tech wire). h. Base of ESP centralizer @ ± 4,246' MD i. 2 joints of 2-7/8" tubing j. Base of centralizer @ ±4,246' MD 20. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 21. Set BPV. Post -Rig Procedure: 22. RD mud boat. RD BOPE house. Move to next well location. 23. RU crane. ND BOPE. 24. NU existing 2-9/16" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 25. RD crane. Move 500 bbl returns tank and rig mats to next well location. 26. Replace gauge(s) if removed. 27. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form rubin 2,16( Min = 2. @I RKB: 27' SCHEMATIC CASING DETAIL Size I Type I Wt Grade I Conn. I ID I Top I Btm 80' 6,620' 5,423' .3,688' 4,312' Milne Point Unit Well: MP L-46 PTD: 215-118 API: 50-029-23551-00-00 UuvcnrL vvcu uvru AP1: 50-029-23551-00-00. PBTD =13,690' MD / 4,177' ND Drilled, Cased and Completed by Doyon 14 -9/17/2015 To= 13,690' MD / 4,177' ND ESP Change -out by ASR t71-10/16/2016 Max Deviation: 94.692 ESP Change -out by ASR #1— 7/19/2017 Revised by TDF 1/4/2019 D 75" 25" 75" 75" rA 00" 30" 30" 30" 20" 0" 0" 0" i0" )0„ 2" shoe @ 3,688' Min @[ Milne Point Unit Well: MP L-46 PTD: 215-118 PROPOSED SCHEMATIC API: 50-029-23551-00-00 Hiles p Ali LFA; RKB: 27' CASING DETAII Site Type Wt Grade Conn. ID Top Btm 80' 6,620' 6,423' .3,688' 4,312' uuvcnMIL vv CLL nvry API: 50-029-23551-00-00 i=13,690' MD / 4,177' TVD Drilled, Cased and Completed by Doyon 14 - 9/17/2015 TD =13,690' MD / 4,177' TVD ESP Change -out by ASR ql —10/16/2016 Max Deviation: 94.892 ESP Change -out by ASR #1-7/19/2017 �D 75" 25" 75" 75" /A 00„ Do„ 30" 30" 30" 20" 0„ .0" 0" El ]0" 2" shoe @ 3,688' Revised by TTW 03/04/2019 Milne Point ASR Rig 1 BOPE 11" BOPE Updated 8/19/2015 3R or Pipe Rams ind UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: March 08, 2019 Subject: Changes to Approved Sundry Procedure for Well MP L-46 Sundry #: xxx-xxx Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date HAK Prepared Procedure Change By (Initials) HAK Approved B (Initials) AOGCC Written Approval Received (Person and Date Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 5, 2019 3:58 PM To: 'Taylor Wellman' Subject: RE: MPL-46 (PTD 215-118) ESP Swap Sundry Looks pretty straight forward... see what I can do Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv schwartz@alaska gov(. From: Taylor Wellman <twellman@hilcorp.com> Sent: Tuesday, March 5, 2019 3:38 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: MPL-46 (PTD 215-118) ESP Swap Sundry Guy, There is a well at Milne Point (L-46) that I would like to be able to perform an ESP swap on in approximately 4-5 days. I know this is much shorter than usual for asking for review. Below is a little more background and attached is a copy of the Sundry application in electronic format. This is an ESP well at Milne Point that recently has failed to surface fluids. We believe the issue to be tubing leaks. This ESP has high corrosion rates due to MIC corrosion and during the last ESP swap we put a specially coated ESP in the well. I would like to pull the completion to see if the tubing is the only failure or if the ESP is also corroded. This is because if a new ESP is needed it can take —4-6 weeks to get the special ordered equipment. With our current schedule with the ASR 1, we have a window to perform this work in 4-5 days or in —6 weeks. I would much prefer the former if possible to avoid further downtime for a well that makes 300-500 bopd. If you have any questions on this please don't hesitate to contact me. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC — Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcoro.com RECE STATE OF ALASKA I . ALI/PA OIL AND GAS CONSERVATION COMWSION REPORT OF SUNDRY WELL OPERATIONS JUL, 3 1 Z017 1.Operations Abandon Li Plug Perforations LJ Fracture Stimulate LJ Pull Tubing U %.,?_aQ, mown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ESP Changeout ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 215-118 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service ❑ 6.API Number: AK 99503 50-029-23551-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0315848,ADL0025509&ADL0025515 MILNE PT UNIT L-46 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 13,690 feet Plugs measured N/A feet true vertical 4,177 feet Junk measured N/A feet Effective Depth measured 13,690 feet Packer measured 6,417 feet true vertical 4,177 feet true vertical 4,157 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,589' 9-5/8" 6,620' 4,174' 5,750psi 3,090psi Production 6,386' 7-5/8" 6,423' 4,156' 6,890psi 4,790psi Liner 7,271' 5-1/2" 13,688' 4,177' 7,740psi 6,390psi Perforation depth Measured depth See Schematic feet SC,ANNEQ /-'"-i G r, True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 4,312' 3,414' Packers and SSSV(type,measured and true vertical depth) Liner Top N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 520 117 1,749 240 211 Subsequent to operation: 193 100 1,652 260 218 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory❑ Development❑� Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-304 Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pchan@hilcorp.com Authorized Signature: AX "C 30 yOfdi_ Date 7/31/2017 Contact Phone: 777-8333 Li //l► ��f,z v.ri//1 RBDMS I,� AUG - 1 2017 Form 10 404 Revised 4/2017 Submit Original Only H . IIIWell: Point Unit Well: MPL-46 PTD:215-118 SCHEMATIC API: 50-029-23551-00-00 tiilcorp Alaska,LLC CASING DETAIL RKB:27' Size Type Wt Grade Conn. ID Top Btm \ 1 20" Conductor 78.6 A-53 Weld 19.25" Surf 80' 20" 9 5/8" Surf.Csg 40 L 80 TC II 8.835" Surf 6,620' 7-5/8" Tieback 29.7 L-80 Vam SLIJ-II 6.820" Surf 6,423' lil I 2 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' TUBING DETAIL 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441" Surf 4,312' JEWELRY DETAIL No. Item Top MD ID OD 1 Tubing Hanger 32' 2 GLM#2-2-7/8"x 1"w/Orifice Valve 142' 2.441" 2.875" 3 Stage Tool—ES Cementer 2,351' 8.618" 9.625" 3 O 4 GLM#1-2-7/8"x 1"Side Pocket w/Dummy 4,027' 2.441" 2.875" 5 XN Nipple 2.313"/2.205"no-go 4,137' 2.205" 2.875" 6 SS Discharge Head-FPDISX 4,179.6' - N/A 7 Pump#1-62 flex 17.5 SXD H6 Monel Coated 4,180' - 4.000" 8 Pump#2-134 flex 17.5 SXD H6 Monel Coated 4,192' - 4.000" 9 SS Gas Separator-GRSFTX AR H6 4,214' - 5.130" 10 SS Upper Tandem Seal-GSB3DB XUT FER HL SSCV 4,219' - 5.130" 4 11 SS Lower Tandem Seal-GSB3DB XLT FER HL SSCV 4,226 - 5.130" 12 SS Motor CL5—XPX:150Hp/2,420V/38Amp 4,233' - 5.620" 13 Sensor-Pheonix XT150 4,244' - 4.50" 14 Centralizer 4,246' - 6.50" n ID= 15 Centralizer—Bottom @ 4,312' 4,310' - 6.50" 4,137' .--:: 5 16 7-5/8"Tam Port Collar 6,353' 6.280" 6 17 Bullet seal Tie Back 8.66'in TBR 6,414' 6.180" 7.350" $ 7 18 Liner Top Packer 6,417' 7.380" 8.300" 5-1/2" LINER DETAIL II 8 Jts Top(MD) Btm(MD) Length illElElEI 9 SOLID 6,443' 6,483' 40' 10 SLOTTED 6,483' 8,592' 2,109' 411 SOLID 8,592' 8,947' 355' SLOTTED 8,947' 9,603' 656' SWELL PKR 9,603' 9,615' 12' 12 SOLID 9,615' 10,217' 602' SWELL PKR 10,217' 10,233' 16' SLOTTED 10,233' 12,248' 2,015' It 0-� 13 SOLID 12,248' 12,639' 391' SLOTTED 12,639' 13,654' 1,015' GENERAL WELL INFO CI D 0 API:50-029-23551-00-00 15 Drilled,Cased and Completed by Doyon 14 -9/17/2015 ESP Change-out by ASR#1—10/16/2016 9-5/8"shoe @ ESP Change-out by ASR#1—7/19/2017 6,260' 5-1/2"shoe @ 1. x;18 /11 y,688' • 17 _________j 111 111 PBTD=13,690'MD/4,177'TVD TD=13,690'MD/4,177'TVD Max Deviation:94.892 Revised by TDF 7/31/2017 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 7/14/17 7/19/17 Daily Operations: 7/12/2017—Wednesday No activity to report. 7/13/2017-Thursday No activity to report. 7/14/2017 Friday Continue to R/U on L-46 and R/D on L-14. Remove catwalk and stage by L-46, Back carrier off of mud boat and stage at L- 46, remove rig floor and well house f/ L-14 in order to access half mats which needed to be set on L-46. Spot mud boat into position once half mats are in place. Remove BOPE f/ L-14 and place in BOP trailer. Spot pit trailer into position. N/U production tree on L-14. 7/15/2017-Saturday Roads and Pads Crane Hoisted well House and Rig floor over Well, Spotted Pit Trailer, Mud Boat Spotted ASR Rig over Center of Well, Raise and Pin top section of Derrick, Spot Cat walk and Pipe Racks, Lay out Hook up Hydraulic Lines to Bops Stack, Rig up Service Lines F/pit module to Rig, Nipple up Spacer Spools on Annular, Function test Bop,Well Head Greg Ruge Tee Bar and Remove BPV and Install TWC Valve in Tubing Hanger Test all Valves and Rams 250psi/2,500psi 5 min each,Test Annular w/2-7/8" Test Joint, 250psi/2,500psi 5 Min each, Record Accumulator Pre-Charge pressures and Chart Test(AOGCC Rep GUY Cook on Location to Witness Testing of Fire and Gas PVT Alarms(Tested Good) (Lou Laubenstein waved to Witness test on 7-15-17 @ 2:53AM) Well Head rep Tee Bar removed TWC Valve, Make up Landing joint into Hanger, BOLDS Pulled Hanger to rig Floor max Pull 30k First joint of pipejLulled very greasy, coated in heavy oil. Close annular, line up and circulate the long way, taking returns to the flow back tank. Catch fluid at surface after 50bbls away, continue to pump watching for returns to clean up at flow back tank. After 168bbls away only 18bbls of crude returned. Close TBG and bullhead 40bbls down IA. IA and TBG on vac. Open annular and prepare to pull TBG. POOH w/ Failed ESP completion f/4,252'md to"3,500'md. Pipe pulling very greasy again, decision made to pump Baraklean sweeps to clean pipe. Pump 30 bbl Baraklean pill. SIMOPS: clean rig floor of excess crude. POOH w/ Failed ESP completion f/—3,500'md to discharge head @ 70'md. Last joint fluid packed, utilize mud bucked to direct fluids into bird bath. Last pup packed with debris. L/D Failed ESP as per Baker Centrilift rep. ESP grounded through pump when performing electrical checks. SIMOPS: Load and tally 8 jnts of 2-7/8" EUE TBG left over f/ L-14 in prep for scraper BHA clean out run. PEAK trucking on location w/290bbls of 140deg seawater in prep for Biocide treatment. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 7/14/17 7/19/17 Daily Operations: 7/16/2017 -Sunday Service Rig Check Fluids and Grease TIH w/7-5/8" Casing Scraper on 2-7/8"Tubing to 2,000'(Bope Drill While Tripping 1.45 sec) Continued TIH f/2.000 'to 4,328 ' (140 Joints) R/U Circulation Hose Circulate Bottoms up. 38 bbl to fill Hole w/ Pump Rate FCP of 3.5 BPM @ 460 psi (Total bbl Pumped 313 bbl.) (Total Fluid Loss 140 bbl.) Rig Maintenance, Oil Change ASR, 100K,300K, Namco, Durst, Work on Cat walk, VMS Shop Mechanic Amos check Belts on Cummins Motor, (Innovation Mud Engineer Mixed 17 Gallons of Biocide into Active System)(400 bbl.Total @ 1,000 PPM) Load and tally 30 Joints of 2-7/8" TBG and trip BHA in the hole F/4,328 ' to 4,952 ' Continue to RIH w/ Baker scraper BHA on 2-7/8"" EUE TBG 1/4,952'md to 5,260'md. Line up and bullhead down the TBG w/400bbls of Biocide f/active system. Pump 2-3BPM w/250-450psi.TBG on a vacuum after circulation. Mix 80bbls of Baraklean in pits and agitate in each pit to clean out any residual Biocide. Bullhead 24bbls down the TBG to clear any leftover Biocide. Bullhead 56bbls of Baraklean down the IA to clean TBG of any crude oil. POOH w/ Baker scraper BHA f/5,260'md to 4,328'md. Perform Kick While Tripping Drill as per standing orders. (70 seconds to shut well in). Perform post drill discussions w/crew. Make adjustments as necessary. Perform rig maintenance as per maintenance list. Service Catwalk, sort and inventory accumulator parts on A pad,go through hydraulic system on Carrier verifying all fittings are snug and no signs of wear. Clean intake screens on pumps, clean rig floor f/left over crude f/trip out of hole w/ ESP. 7/17/2017- Monday Roads and Pads Hauled Flow Back tank f/ MPL-46 to MPI-15, Set Matting Board around well, Well Support Rig up Hard Lines to Flow back Tank and Choke Skid, for Well kill operations on MPI-15, (Change of Plans,ASR Rig Will Now be Moving to MPC-46) We will not get the motor/seals until tomorrow morning. for MPL-46 IWS Crew Tool Pusher, Company Man Looking For a Misplace Packer(7 X 3-1/2 MPR-MP-SPR (26-29),4140 (80), HNGR (90-70-90) 3-1/2 (9.2) NUE) Checked J-Pad Texaco Pad, D-Pad, A-Pad B-Pad Warm Storage Continue to work on ASR#1 maintenance list. Service accumulator,top off accumulator nitrogen levels, clean rig carrier,tool skid, swap out filters on hydraulic system. Company rep and hands drive to C-pad, meet w/ I-rig company rep and discuss logistics and SIMOPS for work on C-46. Prep C-pad location by removing frac tanks, and rolling up containment left from C-46 frac job. Stack timbers on the edge of location. Roads and Pads relocating rig mats from I-pad to C-pad. Well support breaking down hard line set up to kill 1-15 and relocating it to C-46. Continue to clean and service rig and equipment. 7/18/2017 -Tuesday Perform Rig maintenance, ESP Motor/Seal Assembly Arrived on A-Pad at 0910 am Trip out of the hole Lay Down 2-7/8" Tubing and 7-5/8" Casing Scraper 142 joints (ESP Pump Assembly Arrived on Location at 1630 hrs.) R/U to RIH w/ ESP completion on 2-7/8" 6.5ppf EUE TBG. Strap all jnts to verify tally. ESP completion on location after servicing and verification at Centrilift shop. M/U ESP completion as per Centrilift rep including additional 2 centralizers and 2 joints below the motor assembly(not typical configuration) Centrilift rep perform servicing and checks on ESP assembly. RIH w/ ESP completion on 2-7/8" 6.5ppf EUE TBG as per sundry.to 4,850' Perform electrical verification @ surface, 500'md, 2,000'md and every 2,000'md there after. Circulate through ESP every 2,000'md to ensure clear of debris. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 ASR#1 50-029-23551-00-00 215-118 7/14/17 7/19/17 Daily Operations: 7/19/2017-Wednesday Service Rig Check Fluids and Grease TIH w/2-7/8"Tubing and ESP Pump Assembly f/4.250 ft. to 4,312 ft. Pick up Landing Joint Make up into Tubing Hanger, Centrilift Rep Splice ESP Cable into Pentratror Land Tubing Hanger RILDS Break and Lay down Landing Joint P/U/W=32K D/N/W=19K Well Head Rep Greg Ruge Tee Bar Installed BPV in Hanger Profile (Release ASR Rig at 11: 30 am) Blow down all service Lines, Disconnect Accumulator Lines, Nipple down bop stack to Four Bolts, Remove pipe Racks cat walk, Hilcorp Electricians Disconnect Fire and Gas Alarms, Haul off 520 bbls Sea Water to B-50,Vac Truck Super Sucker Clean Pits Break over Top Section Lay over Derrick, Move ASR Rig to MPC-Pad,ASRC Crane Remove Rig Floor and Well House, Nipple down Bop Sack Load Bop House Trailer, Haul Cat Walk Pipe Racks,to MPC-Pad, (Schlumberger E- Line Arrived on MPC-46 at 1430 hrs.) Nipple up Production Tree, Test Hanger Void 5,000 Psi, Final ESP Check(tested Good) Clean Cellar and Location. 7/20/2017 -Thursday No activity to report. 7/21/2017- Friday No activity to report. 7/22/2017-Saturday;,, No activity to report. 7/23/2017 -Sunday No activity to report. 7/24/2017- Monday No activity to report. 7/25/2017-Tuesday No activity to report. • • t, Or jy��•9 THE STATE Alaska Oil and Gas of/� LAsKA Conservation Commission 1-1 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 g1i� Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manger SCANNEDi` 1# Hilcorp Alaska, LLC � 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU L-46 Permit to Drill Number: 215-118 Sundry Number: 317-304 Dear Mr. York: 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, 6Dar4\—_ Hollis S. French Chair DATED this 3 day of July, 2017. RBDMS r - JUL 1 1 2017 • SRECEIVED STATE OF ALASKA JUN 3 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OG Or 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing Q Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: ESP Change-out ✓❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC ` Exploratory ❑ Development 2. 215-118 r 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-23551-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes 0 No ❑., / MILNE PT UNIT L-46 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0315848, ADL0025509, ADL0025515 • MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,690' * 4,177' • 13,690' • 4,177's 831 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,620' 9-5/8" 6,620' 4,174' 5,750psi 3,090psi Production 6,423' 7-5/8" 6,423' 4,156' 6,890psi 4,790psi Liner 7,271' 5-1/2" 13,688' 4,177' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic -/ See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 4,254' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): G/ 7 i IPS N/A and N/A N/A,aacKA il 1 1 AND 12.Attachments: Proposal Summary 0 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program • ❑ BOP Sketch ❑., Exploratory 0 Stratigraphic 0 Development❑✓ r Service 0 14.Estimated Date for 15.Well Status after proposed work: 7/17/2017 Commencing Operations: OIL E . WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pChBn(C7hiIcorp.COm Contact Phone: 777-8333 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 3o `f Plug Integrity 0 BOP Test' Mechanical Integrity Test 0 Location Clearance 0 Other: 9* 200 E'Si1 �L Post Initial Injection MIT Req'd? Yes 0 No ❑ RBDMS L t-- JUL 1 1 2017 Spacing Exception Required? Yes 0 Nod \c,Subsequent Form Required: , --404 APPROVED BY I-4 I Approved by: COMMISSIONER THE COMMISSION Date: (e 3a / ' "77 N►zg 'Mn ,(1 G+ A Submit Form and �� Form 10-403 Revised 4/2017 ® r v p i s slid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU L-46 Ilacorp Alaska,LD Date:06/29/2016 Well Name: MPU L-46 API Number: 50-029-23551-00 Current Status: Oil Well [Failed ESP] Pad: L-Pad Estimated Start Date: July 17th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 215-118 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,231 psi @ 4,000' TVD (SBHPS 06/20/2017/5.93 ppg EMW)t,/ Maximum Expected BHP: 1,231 psi @ 4,000' TVD (No new perfs being added)( MPSP: 831 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-46 was drilled and completed in September 2015 as a horizontal Schrader Bluff ESP producer completed with slotted liner. ESP history: September 2015 (initial install) and October 2016. The ESP has failed. Notes Regarding Wellbore Condition • 9-5/8" x 7-5/8" casing annulus tested to 1,000 psi for 30 minutes 09/15/2015 .f• CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. v OtL SA f'r ct.ekv.) Objective: Pull failed ESP and run a new ESP. f Pre-Rig Procedure: 1. Clear and level pad area in front of well.Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg fluid down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. Well Prognosis Well: MPU L-46 Ililcarp Alaska,LU Date:06/29/2016 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg fluid brine prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High,annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr.Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor cL" ', the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking 4' anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg NaCI brine as needed. 15. MU landing joint or spear and PU on the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used. Lay down failed ESP. Replace bad joints of tubing as necessary. 18. PU bit/scraper on 2-7/8"tubing and RIH to^'4300' MD. Circulate/reverse circulate the wellbore clean at maximum rate. POOH and LD bit/scraper. 19. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±4,250' MD. a. Upper GLM @ ± 135' MD w/SO b. XN Nipple @ 4,165 MD c. Base of ESP @ ±4,250' MD 20. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. S • Well Prognosis Well: MPU L-46 Hilcorp Alaska,Lr.) Date:06/29/2016 21. Set BPV. Post-Rig Procedure: 22. RD mud boat. RD BOPE house. Move to next well location. 23. RU crane. ND BOPE. 24. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 25. RD crane. Move 500 bbl returns tank and rig mats to next well location. 26. Replace gauge(s) if removed. 27. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form • . ! Milne Point Unit 11 Well: MPL-46 PTD: 215-118 SCHEMATIC API: 50-029-23551-00-00 Ha.,:u.,.k..I.1.c CASING DETAIL RKB:27' Size Type Wt Grade Conn. ID Top Btm 1 20" Conductor 78.6 A-53 Weld 19.25" Surf 80' 20"',r" ' 4 ;/-e � 9-5/8" Surf.Csg 40 L-80 TC II 8.835" Surf 6,620' 2 7 5/8" Tieback 29.7 L 80 Vam SLID II 6.820" Surf 6423' I 57:51//82: 1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' - TUBING DETAIL 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441" Surf 4,254' JEWELRY DETAIL No. Item Top MD ID OD 1 Tubing Hanger 27' 2 GLM#2-2-7/8"x 1"w/Orifice 133' 2.250" 3.680" i 3 Stage Tool—ES Cementer 2,351' 8.618" 9.625" 3 Qiir 4 GLM#1-2-7/8"x 1"w/Dummy 4,016' 2.250" 3.680" 5 XN Nipple 2.313"/2.205"no-go 4,165' 2.205" 3.680" LL 41.4. 6 Discharge Head-FPDIS 4,184.6' - N/A 7 Pump#1-62FLEX17.5,SXD H6 4,185' - 4.000" 8 Pump#2-134FLEX17.5,SXD H6 4,197' - 4.000" .,',..*..iI 9 Gas Separator-GRS FER N AR 4,222' - 5.380" 10 Upper&Lower Tandem Seal-GSB3DBUT SB/SB PFSA 4,225' - 5.130" :*, 11 Motor CL5-MSP3-250 4,239' 5.62" 12 Sensor-Pheonix XT150 4,250' 4.500" ii114 „ 13 Centralizer—Bottom @ 4,245' 4,252' 5.850" . ' 14 7-5/8"Tam Port Collar 6,353' 6.280" 4 15 Bullet seal Tie Back 8.66'in TBR 6,414' 6.180" 7.350" 16 Liner Top Packer 6,417' 7.380" 8.300" , 5-1/2" LINER DETAIL >rj 5 '; Its Top(MD) Btm(MD) Length ',11 1::! 3 ' y SOLID 6,443' 6,483' 40' 6 ''... SLOTTED 6,483' 8,592' 2,109' ' 7 , SOLID 8,592' 8,947' 355' SLOTTED 8,947' 9,603' 656' r 8 SWELL PKR 9,603' 9,615' 12' t'' HID 9 SOLID 9,615' 10,217' 602' SWELL PKR 10,217' 10,233' 16' 10 SLOTTED 10,233' 12,248' 2,015' SOLID 12,248' 12,639' 391' '' SLOTTED 12,639' 13,654' 1,015' 11 12 a 13 9-5/8"shoe @ .. 6,260' ., `"A _.----___ 5 1/2"shoe @ 14 kA 16 I�' IY `___.._-_._ 13,688' • \ 15 - } GENERAL WELL INFO PBTD=13,690'MD/4,177'TVD API:50-029-23551-00-00 TD=13,690'MD/4,177'TVD Drilled,Cased and Completed by Doyon 14 -9/17/2015 Max Deviation:94.89° ESP Change-out by ASR#1—10/16/2016 Revised by TDF 11/1/2016 Milne Point Unit . • • Well: MPL-46 PTD:215418 PROPOSED API: 50-029-23551-00-00 Hik+"rp Ma,ku.LLC CASING DETAIL RK6:27' Size Type Wt Grade Conn. ID Top Btm ". 1 �`'1-4 20" Conductor 78.6 A-53 Weld 19.25" Surf 80' 20' 4,,30 14 lis 9 5/8" Surf. Csg 40 L-80 TC II 8.835" Surf 6,620' L7-5/8" Tieback 29.7 L-80 Vam SLIJ-II 6.820" Surf 6,423' t.' 2 w 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' TUBING DETAIL 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441" Surf 4,254' . : JEWELRY DETAIL No. Item Top MD ID OD 1 Tubing Hanger 27' "` 2 GLM#2-2-7/8"x 1" ±133' 2.250" 3.680" `a 3 Stage Tool—ES Cementer 2,351' 8.618" 9.625" 3 -A 4 GLM#1-2-7/8"x 1" ±4,016' 2.250" 3.680" 04 irr4 5 XN Nipple 2.313"/2.205"no-go ±4,165' 2.205" 3.680" :67I"4:4,1, 6 Discharge Head-FPDIS _4,184.6 - N/A 7 Pump ±4,185' - 4.000" 8 Pump ±4,197' - 4.000" 9 Gas Separator ±4,222' - 5.380" p7 ., 10 Upper&Lower Tandem Seal- ±4,225' - 5.130" 41 11 Motor ±4,239' - 5.62" 'rtt 1 2;412 Sensor ±4,250' - 4.500" il 13 Centralizer ±4,252' - 5.850" , it 4 , ,` 14 7-5/8"Tam Port Collar 6,353' 6.280" 15 Bullet seal Tie Back 8.66'in TBR 6,414' 6.180" 7.350" 16 Liner Top Packer 6,417' 7.380" 8.300" 5 6 5-1/2" LINER DETAIL ' Jts Top(MD) Btm(MD) Length i¢ 8 SOLID 6,443' 6,483' 40' 1 41. , SLOTTED 6,483' 8,592' 2,109' MIL 9 . 1 SOLID 8,592' 8,947' 355' 110 SLOTTED 8,947' 9,603' 656' SWELL PKR 9,603' 9,615' 12' SOLID 9,615' 10,217' 602' SWELL PKR 10,217' 10,233' 16' ' 11 SLOTTED 10,233' 12,248' 2,015' SOLID 12,248' 12,639' 391' SLOTTED 12,639' 13,654' 1,015' '. a 12 13 9-5/8"shoe @ °�' ' -e.- 1, 6,260' *1' 4:5.. `5. - 4'' 5 1/2"shoe @ 11.1416 v { 13,688' . „ 15 GENERAL WELL INFO PBTD=13,690'MD/4,177'TVD API:50-029-23551-00-00 TD=13,690'MD/4,177'TVD Drilled,Cased and Completed by Doyon 14 -9/17/2015 Max Deviation:94.892 ESP Change-out by ASR#1-10/16/2016 Revised by PC 2017-06-30 • • • II Milne Point ASR Rig 1 BOPE 11" BOPE Stripping Head / ,1 3.98' / Shaffeo 11" - 5000 ,.., 1 III illi ill 71-) i1 )I•t i 1 j4i LI-If 4.54' °. , 0 = VBR or Pipe Rams 11" 5000 - Blind 0,14 w. lit tit litlit I_ 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves 17,) t _ fy ft) ' - ,t t- 71 2.00' ` ,(�, 1 `o�;� 111 lit 111 111 Ilia �! -. Manual Manual Manual HCR Updated 8/19/2015 • . • • WELL L-46 Tree Cap. Otis style,5%" ACME 2 9-16"5K,FE,DD L-U 06-30-2017 PN A26299-003 DATE SN H456418 11111 ... Swab valve Seaboard Model 510, 2 9/16"5K, 7 FE,DD L-U PN 564650-DB1 _ SN 0100-57293-1-062 _ 0 A le Wit I — Wing valve Seaboard Model 00000 ` 510, 2 9/16" 5K, FE,DD L-U 110® Com) 0 PN 564650-DB1 a SN 0100-57293-1-093 Tbg Hgr,Seaboard SM- °p®A 11111111.1 E-CL 11 x 2 7/8" EUE BOX top and bottom,2 ..4/.... SSV valve Seaboard Model 1/2" "H" BPV, ported510,2 9/16" 5K,FE,DD L-U. for 2ea 3/8" Control ' 0 With Safeco 4000 series line,w/4' pup L-U,DD- omi�� actuator, hydraulic ._ NL, For use with Taurus PN 353799 T-57 penetrator system SN H456273 PN W12655-001 71 SNH457680 in Lr ,_Iu � ', Master valve Seaboard Model t! —1— .14 510, 2 9/16" 5K,FE,DD L-U — 'rlPN 564650-DB1 Taurus T57 �•— ( SN 0100-57293-1-091 penetrator,5Kv/154 l' —�1 --- 1 1 Amps. PN WT57-F48- - -. ; t API 11 " 51( .i r 1 523-00 F � I �� Sir rrL____Jo n1 1 �rn u 1 P { -` API 16%" 3K iii, ; 9 5/8" Csg Hgr, Seaboard t ' r ' . ' SM-B-22 11 x 10.5-4 �'�� .o, -.:/jStub Acme top x 9 5/8" DWC BOX bottom,w/ � �' 3' pup r i LU,DD-NL PN W11840-001 , L 1 SN EI I lid a _l - • 0 § k2 a) Pao a \ J2/ g c> o@ q a)0. co.0 0 2 ) « tea oE S o E 2 2 = E > 2 ° « @ ' / E � o. 2k � M $ 2 $ 1— § k �a ■ = / / a. � % / 4m a ■ 2 \ I o Co $ % E7 k 17 ) o Ta•11 o 2 / -1 0. k/ 7 as `§ _ = U CO \ ' _ 0 2 U) J \ 9 � 4, 112E § 'hal 0 = 0 a 2 / 'e o 4 .0 / ti 0. TS0) c \ / ca c �itea 2 _ # Ca C)f \ I/ § / ƒ Co 0 / 4L 0.o. / o Co .a) / Q. o R %o E - 2 aCD cm k m : d _ C C a) ■ ( 2 04 C -) 0 / >, Co 2 67 2. : � � k t. E0 / 2 . 0 o Cl) k k 0tii o_ 0 STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: ESP Changeout 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 215-118 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23551-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0315848,ADL0025509,ADL0025515 MILNE PT UNIT SB L-46 RECEI ED V 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL NOV 0 8 2016 11.Present Well Condition Summary: A0 G CO Total Depth measured 13,690 feet Plugs measured N/A feet true vertical 4,177 feet Junk measured N/A feet Effective Depth measured 13,690 feet Packer measured N/A feet true vertical 4,177 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,620' 9-5/8" 6,620' 4,174' 5,750psi 3,090psi Production 6,423' 7-5/8" 6,423' 4,156' 6,890psi 4,790psi Liner 7,271' 5-1/2" 13,688' , 4,177' 7,740psi 6,390psi Perforation depth Measured depth See Attached Schematic w_ 44Al''' e 3 2.6 4 V a a True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,254' 3,389' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 720 0 Subsequent to operation: 450 56 2,010 320 292 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory El Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-498 Contact Paul Chan \ EmailP chan anhilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date 11/3/2016 2Z /,a-5-16 ,f . O,f7/4 RBDMS w NOV 1 0 2016 Form 10-404 Revised 5/2015 Submit Original Only Well: MPMilne PointL46 Unit • H . SCHEMATIC PTDPI::5201-50- 0 2150 A2191-823551-00-00 llikorp Alaska,LLC CASING DETAIL RKB:27' Size Type Wt Grade Conn. ID Top Btm 1 20" Conductor 78.6 A-53 Weld 19.25" Surf 80' 20' �I. 9-5/8" Surf. Csg 40 L-80 TC 11 8.835" Surf 6,620' 7-5/8" Tieback 29.7 L-80 Vam SLIJ-II 6.820" Surf 6,423' 2 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' °`+' TUBING DETAIL 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441" Surf 4,254' ,4 JEWELRY DETAIL f No. Item Top MD ID OD 1 Tubing Hanger 27' 2 GLM#2-2-7/8"x 1"w/Orifice 133' 2.250" 3.680" 3 Stage Tool—ES Cementer 2,351' 8.618" 9.625" 3 Q 4 GLM#1-2-7/8"x 1"w/Dummy 4,016' 2.250" 3.680" 5 XN Nipple 2.313"/2.205"no-go 4,165' 2.205" 3.680" 6 Discharge Head-FPDIS 4,184.6' - N/A 7 Pump#1-62FLEX17.5,SXD H6 4,185' - 4.000" 8 Pump#2-134FLEX17.5,SXD H6 4,197' - 4.000" 9 Gas Separator-GRS FER N AR 4,222' - 5.380" t 10 Upper&Lower Tandem Seal-GSB3DBUT SB/SB PFSA 4,225' - 5.130" i 11 Motor CLS-MSP3-250 4,239' - 5.62" " 12 Sensor-Pheonix XT150 4,250' - 4.500" 13 Centralizer—Bottom @ 4,245' 4,252' - 5.850" .1 I 14 7-5/8"Tam Port Collar 6,353' 6.280" 4 15 Bullet seal Tie Back 8.66'in TBR 6,414' 6.180" 7.350" 16 Liner Top Packer 6,417' 7.380" 8.300" 5-1/2" LINER DETAIL 5 its Top(MD) Btm(MD) Length SOLID 6,443' 6,483' 40' 6 SLOTTED 6,483' 8,592' 2,109' 7 SOLID 8,592' 8,947' 355' SLOTTED 8,947' 9,603' 656' 8 SWELL PKR 9,603' 9,615' 12' s:° ' ililitili 9 `i SOLID 9,615' 10,217' 602' f —` SWELL PKR 10,217' 10,233' 16' i. 10 SLOTTED 10,233' 12,248' 2,015' SOLID 12,248' 12,639' 391' ra � SLOTTED 12,639' 13,654' 1,015' \ 11 t` 0',] 12 ' 13 9-5/8"shoe @ 4,1.4: '�� III3 5-1/2"shoe @ 1 7i 16 j/I ,II CI c.1,`,A `'..=`rR.. =,.,'rJ tt.t. .....,1„7.5 GENERAL WELL INFO PBTD=13,690'MD/4,177'TVD API:50-029-23551-00-00 TD=13,690'MD/4,177'TVD Drilled,Cased and Completed by Doyon 14 -9/17/2015 Max Deviation:94.899. ESP Change-out by ASR#1—10/16/2016 Revised by TDF 11/1/2016 s Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 Doyon 14 50-029-23551-00-00 215-118 10/10/16 10/16/16 Daily Operations: ; ` ; " i0 10141,1' 10/5/2016-Wednesday ��Di qI11li 1}I10$@6�,, No activity to report. 10/6/2016-Thursday No activity to report. 10/7/2016- Friday No activity to report. 10/8/2016-Saturday No activity to report. 10/9/2016-Sunday No activity to report. 10/10/2016- Monday Continue to lay mats in front of rig. Move rig down L-Pad access road and arrive L-Pad @ 10:30 hrs. Remove front and rear boosters and star wars. Back around corner and attempt to MIRU MP L-46.Area too tight with well house on drillers side and high pressure line on off driller side. Call out crane and remove wellhouse. General housekeeping on rig. Back Doyon 14 over MP L-46. Shim up rig. Skid rig floor into position. Rig up rig floor lines. Skid conveyor into position. Hook up mud pump lines. Spot flow bank tanks and rig up hardline. Rig up circulating manifold in cellar. Spot slop tank and rig up shute. ✓' Continue hooking up mud pump lines. Spot peak truck and take on 50 bbls of water. Move fluid through pits to ensure integrity of lines. Fill mud pumps with oil. Blow air through line and PT hardline. Pull BPV.Take on remaining 8.7 ppg brine. 10/11/2016-Tuesday Initial tubing pressure 600psi, IA 700psi, bleed down to 125psi. Line up to pump 8.7 ppg KWF.Trouble shoot pump gauges and stroke counter. Check wires and connections-wired incorrectly. Bleed off pressure from well from 275psi to 75psi. Begin pumping 350bbls of KWF 8.7ppg NaCI brine staging pumps up to 3 bpm. ICP 1,070psi casing pressure 210psi. FCP 825psi. 350bbls pumped, 200bbls returned. Monitor well, pressure bleeding off. Flush circulating lines out to kill tank. Continue circulating 8.7 ppg KWF at 3 bpm 620psi.At 65bbls pumped observe brine back. 95bbls pumped 70bbls returned. Monitor well while offloading flowback tanks and loading pits with 8.5 ppg seawater.Allow IA to flowback, initial 2.5 bpm crude/gas/seawater returned. Rate slowed to minimal, observe all gas back.Shut in. SICP build to 175,SITP 80psi.SITP 80psi, SICP 160psi. Circulate 220bbIs 8.5 ppg seawater at 3 bpm 490psi. 190bbls returned. Monitor well initial SITP 150psi, / SICP 60psi increasing to 160/100psi in 3 hours.Take on 3% KCL brine from ASR and weigh up to 8.7 ppg. Sim Ops: bring up XO's and safety valve; C/O saver sub to 3-1/2" IF. Line up and bullhead 250bbls 8.7ppg brine down tubing staging pumps up to 3 bpm ICP 830psi increasing to 900psi. Note: 3bbls of 8.7 brine spilled to pad,Victrolic clamp from charge pump leaking. ACS contacted. Cleanup of fluid/gravel not underneath rig begin. Monitor well ISITP 340psi, ISICP 270 dropping to FSITP 260, FSICP 200psi. Mix heated 8.7ppg brine in pits.Circulate 250bbls heated 8.7ppg brine around. Bring pumps up to kill rate holding casing pressure. Swap to pump pressure and hold. Pump 250bbls, 150bbIs back. Monitor well. SITP/SICP= 340/240 decreasing to 280/140 in 2 hours. Consolidate fluid in pits. Suck out flow bank tank. s • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 Doyon 14 50-029-23551-00-00 215-118 10/10/16 10/16/16 Daily Operations: i a E � 10/12/2016-Wednesday Monitor well.Tubing @ 130, IA @ 160. Pump 3 bpm down tubing @ 3bpm holding back pressure on the annulus. Pump until good clean 8.7 brine back. No Gas.Shut down and monitor well.Annulus built to 180psi in 30 min. Bled down 50 bbl from the annulus. Shut in and pressure built to 100psi in 30 min. Bled down 37 bbl in 30 min. Shut in while weighting up pits to 9.1 Annulus built to 105 psi &stabilized. Circ 220 bbl 9.1 in and out holding 50 psi over on the annulus. Good 9.1 back. Lost 6 bbl during circulation. Shut down. Monitor well.Tubing @ 20 Annulus @ 40 Bleed back on annulus 12 bbl in 30 min. Shut in. Monitor well.Annulus built back to 40 &tubing @ 20. Discuss with completion engineer and decide to weight up to 9.5. Bring weight up in pits to 9.5. Continue to R/U rig floor to pull ESP. Hang up ESP Sheave in derrick. R/U Belly board for 2-7/8". R/U &Test electrical on ESP Spooling unit. Pump 9.5 in and out. Shut down and monitor well.Tubing and annulus static. Monitor 10 min. Good. Set BPV @ 1,800. Blow down and rig down circulation lines. Nipple down 2-1/16" production tree and hang in cellar. Nipple up 11" x 13-5/8" adapter spool. Nipple up BOP. Install koomey, choke and kill / lines. Obtain RKB's. SimOps: weigh up fluid in pits from 9.1 ppg to 9.5 ppg. Install 2-7/8" x 5" VBR in upper and lower pipe ram cavity. Install blind rams. Rig up testing equipment. Make up XO's and safety valves. Grease choke manifold.Install riser and mouse hole. 10/13/2016-Thursday Pressure up Accumulator&Test. Failed shut down.Trouble shoot. Work On accumulator rig on down time. Install elephant trunk on ESP sheave. Pull BPV. Fill hole with 9.5 brine. Static loss rate of 12 BPH. Set TWC. R/U to test bops with 2-7/8" test / joint. Perform body test to 250/2,500psi. Good. Call out state man. Wait on state man. Clean and clear the rig. Performed first test. Had to change out chart recorder.Test gas alarms. Good.Test BOPE as per Doyon 14 procedure. One fail/pass- lower pipe rams,function and retest-good. Perform Koomey and PVT tests-good. Rig down testing equipment, blow down lines, cut 121' excess drilling line. Inspect saver sub. Grease IBOP and adjust brakes.Suck out stack. Bring WTF pipe handling equipment to rig floor. Suck out stack. Pull TWC. Rig up to pull 2-7/8" tubing. Rig up Weatherford. 10/14/2016-Friday R/U to pull 2-7/8" with Baker&Weatherford. BOLD, Pull hanger to the floor @ 66k. Fill hole and monitor static loss rate @ 12 BPH. Pull out of the hole F/4,253'T/the ESP pump. L/D two GLMs, XN nipple. One single. Stood back 43 stands. Found one damaged pin on stand # 19. Will change out on trip in. No damage visible on cable. L/D ESP Assembly. Found very bad corrosion on motor&seals. Flat clamps rotted through and btm one missing. See Pics. Static loss for the tour still 12 bph. Contact Baker Huges and call out mill and boot baskets. Clean and clear rig floor. Rig down old spooler and sheave. Prep subs and XO's for cleanout run. Change out link tilt bails. Make up clean out assembly. 6-3/4" mill,two boot baskets, bit sub and XO. RIH with 2-7/8" work string, changing out three joints(bad pins). Pick up additional 9 joints from shed to 4,386'. PUW 60K SOW 58K. Make up XO and circulate staging pumps up to 6 bpm 1,280psi. Obtain SPR's. Monitor well (dropping). Blow down top drive. POOH with cleanout assembly to 331', laying down excess 10 joints. 10/15/2016-Saturday Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP L-46 Doyon 14 50-029-23551-00-00 215-118 10/10/16 10/16/16 v ari x � �� I� 1,14 f c o,a��y Operations: J y� �� ti� POOH racking back 2-7/810/15/2016-Saturday in the derrick. L/D Clean out BHA. Found 8" peace of flat guard in boot basket. Hung double esp sheave. Installed esp cable &cap string. Drain stack. Found remaining missing flat guard sitting on tubing spool. Built magnet mount for T bar. with 12.25" centralizer. Built esp assembly from centralizer to upper seals and serviced same while waiting for fishing tools. Attempt to fish flat guard with magnet. Flat guard fell off. Wait on sting magnet for clean out BHA#2. Prep for BHA#2 clean out run with string magnet. Hot shot truck stuck behind rig move prep. P/U 6.75"Junk Mill,two boot baskets, 6" string mill. RIH assembly to 4,455'. PUW 60K, SOW 60K M/U crossover and stage pumps up to 5 bpm 890psi. Blow down top drive. Monitor well, fluid dropping. POOH laying down 2-7/8" 8rd EUE tubing. Sim Ops: load pipe shed of new tubing and strap. Lay down magnet, boot baskets, and mill. Boot baskets empty. Minimal metal shavings on magnet. Clean and clear rig floor. Continue processing tubing in pipe shed. Pick up ESP motor and seal assembly from mousehole. Pick up and make up ESP pumps. Connect CAP tubing and ESP cable. Install two flat clamps, 6 pump clamps,three protectorlizer clamps. Meg test ESP cable -good. Check check valve for Cap tubing-good. RIH with ESP completion as per detail to 465' installing cannon clamps every joint to joint 8 and every other joint after. 10/16/2016-Sunday RIH with 2-7/8" EUE picking up singles F/85'T/4,222'. Install canon clamps on the first 8 joints and then every other joint. Total clamp count on pump-6 Pump clamps, 3 Protectrolizer, 2 flat guard. & 75 canon clamps. Run a total of 132 joints& 2 GLMs. One XN nipple. M/U hanger.Terminate ESP cable in hanger. M/U Penetrator.Terminate cap string in hanger.Test cap string and Meg cable Good. Land hanger. UP/DN 62/57. Blocks wt is 40k. RILD, Back out landing joint. Install BPV, Bleed down Accumulator. Clean and clear rig floor. Rig down pipe handling equipment, control line sheave. Clear floor of Weatherford and Centrilift equipment. Unload pipe shed of used 2-7/8" tubing. Pull riser and mouse hole. Remove kill line. Nipple down BOP stack and set back on stump. Sim Ops: change out saver sub to 4-1/2" IF. Nipple up 2-1/16" tree. PT tubing void 250/5,000-good. Pull BPV, set TWC. Rig up and test tree. 250/5,000psi -good. Clear cellar, secure tree. Blow down hardline and disconnect. Remove shute from slop tank. Prep to skid rig floor.Skid rig floor. 10/17/2016-Monday No activity to report. 10/18/2016-Tuesday No activity to report. II • • OF TtJ . e,\ 1,7,-,-.� 9 THE STATE Alaska Oil and Gas 4.41 ,-tom ofeLrV A Conservation Commission Witii i� 333 West Seventh Avenue '41r14 C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ` h' Main: 907.279.1433 (4.4tLAS*P.' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager CANSEC) V EE' I o 2117, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB L-46 Permit to Drill Number: 215-118 Sundry Number: 316-498 Dear Mr. York: 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, P9t)&14 Cathy . Foerster Chair DATED this 76day of September, 2016. RBDMS t tz Out 0 3 2016 CE .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEN 2 9 2O APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 GC 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other. ESP Changeout IQ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development D. 215-118 3.Address: 3800 Centerpoint Dr,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-23551-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 477.05 ' Will planned perforations require a spacing exception? Yes ❑ No 0 I MILNE PT UNIT SB L-46 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 315848, 025509, 025515 • MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ' 13,690' ' 4,177' . 13,690' • 4,177' 1,337 / N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' N/A N/A Surface 6,620' 9-5/8" 6,620' 4,174' 5,750psi 3,090psi Production 6,423' 7-5/8" 6,423' 4,156' 6,890psi 4,790psi Liner 7,271' 5-1/2" 13,688' 4,177' 7,740psi 6,390psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic . See Attached Schematic 2-7/8" 6.5#/L-B0/EUE 8rd 4,253' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory p Stratigraphic ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/13/2016 Commencing Operations: OIL Q' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan@hilcorp.com Printed Name Bo York Title Operations Manager Signatura......--cd) °G/'C Phone 777-8345 Date 9/28/2016 COMMISSION USE ONLY Date f approval: Notify Commission so that a representative may witness Sundry Number 3k(.12.-1—f 1$ Plug Integrity ❑ BOP Test EJ. Mechanical Integrity Test ❑ Location Clearance El Other: oo �J S G z1 Pe gIZ411L Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 'a—il en RBDMS (---OCT'0 3'2016 APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: f)�Z9�T 5A �� `1I 21t4' P 7M•/L '9 4 Submit Form and Form 10-403 Revised 11/2015 , {�444G�inAv lid for12months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU 1-46 Ililcora Alaska,LL' Date:09/28/2016 Well Name: MPU L-46 API Number: 50-029-23551-00 Current Status: Oil Well [Failed ESP] Pad: L-Pad Estimated Start Date: October 13th, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 215-118 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number., 1652861. Job Type: '11,r_-11 ESP'repair Current Bottom Hole Pressure: 1,737 psi @ 4,000' TVD (SBHPS 08/22/2016/8.36 ppg EMW) Maximum Expected BHP: 1,737 psi @ 4,000' TVD (No new perfs being added) ,, MPSP: 1,337 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-46 was drilled and completed in September 2015 as a horizontal Schrader Bluff ESP producer completed with slotted liner. The ESP has failed. Notes Regarding Wellbore Condition • 9-5/8" x 7-5/8" casing annulus tested to 1,000 psi for 30 minutes 09/15/2015, • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. ,/ Objective: tt°` 310 24. Pull failed ESP and run a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.7 ppg NaCI brine down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • Well Prognosis Well: MPU L-46 IIiieorp Alaska,LLQ Date:09/28/2016 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.7 ppg NaCI brine prior to pulling BPV. Set 12 Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. sr b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. nn (.0i' b. With stack out of the test path, test choke manifold per standard procedure re,5(/' c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.7 ppg NaCI brine as needed. 15. MU landing joint or spear and PU on the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. PH and lay down the 2-7/8"tubing. Number all joints. Tubing will be re-used. Lay down failed ESP. Replace bad joints of tubing as necessary. 18. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at±4,250' MD. a. Upper GLM @ ± 150' MD w/SO g ;e b. XN Nipple @ 4,175 MD c. Base of ESP @ ±4,250' MD d. CO 390A: No packer since reservoir pressure is below 8.55 ppg EMW. 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. • Well Prognosis Well: MPU L-46 Ililcorp Alaska,LLI Date:09/28/2016 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form 0 • Milne Point Unit Well: MPL-46 SCHEMATIC PTD: API: 50-029-21511823551-00-00 uaorn,aw.aa,Lu: 1KB:27' CASING DETAIL ' \ / 1 **V'- Size Type Wt Grade Conn. ID Top Btm 20' .:; 0,164420" Conductor 78.6 A-53 Weld 19.25" Surf 80' se 2 9 5/8" Surf.Csg 40 L 80 TC II 8.835" Surf 6,620' % *4' x:, 7-5/8" Tieback 29.7 L-80 Vam SLID-II 6.820" Surf 6,423' .,� „; 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' .41 TUBING DETAIL 2-7/8" Tubing 6.4 L-80 EUE 8rd 2.441" Surf 4,253' i . s c.= JEWELRY DETAIL 3Q,. No. Item Top MD Btm MD ID OD 1 Tubing Hanger 27' 31.62' 2 GLM w/Orifice 136' 145' 2.250" 3.680" - 3 Stage Tool—ES Cementer 2,351' 2,354' 8.618" 9.625" kot 4 GLM w/Dummy 4,025 4,034' 2.250" 3.680" 5 X Nipple 2.313"/2.205"no-go 4,176' 4,177' 2.250" 3.680" 6 ESP Assembly 4,195' 4,253' 5.850" ' 7 7-5/8"Tam Port Collar 6,353' 6,356' 6.280" :'` 8 Bullet seal Tie Back 8.66'in TBR 6,414' 6,423' 6.180" 7.350" 9 Liner Top Packer 6,417' 6,432' 7.380" 8.300" 1 i 10 Swell Packer(2 Total—See Detail Below) See Below See Below 4.892" 8.000" 5-1/2"SOLID LINER DETAIL 5-1/2"SLOTTED LINER DETAIL Jts Top(MD) Btm(MD) Top(MD) Btm(MD) 1 6,443', 6,483' 6,483' 8,592' 4 9 8592' 8,947' 8,947' 9,603' 15 9,603' 10,233' 10,233' 12,248' 'r 10 12,248' 12,639' 12,639' 13,654' 5 SWELL PACKER DETAIL . Al Top(MD) Btm(MD) ililJli 9,609.02' 9,614.71' 10,222.59' 10,228.28' it 0 1.. 19-5/8"shoe @ I I 6,260' `' 5-1/2"shoe @ !!e1 9 10 13,688' 8 � ill i� d PBTD=13,690'MD/4,177'TVD b w ° t. , -r ,"°4 -74 TD=13,690'MD/4,177'TVD Max Deviation:94.89° Updated by CJD 9/29/15 IIIMilne Point Unit lit 0 Well: MPL-46 PTD:215-118 PROPOSED API: 50-029-23551-00-00 Ifikera Alaska.L.I.( RKB:27' CASING DETAIL '' \ / 1 % I Size Type Wt Grade Conn. ID Top Btm 20" .`, 20" Conductor 78.6 A-53 Weld 19.25" Surf 80' 2 9-5/8" Surf.Csg 40 L-80 TC II 8.835" Surf 6,620' 7-5/8" Tieback 29.7 L-80 Vam SLID-II 6.820" Surf 6,423' .`'. 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' ill TUBING DETAIL 2-7/8" Tubing 6.5 L-80 EUE 8rd 2.441" Surf ±4,250' P JEWELRY DETAIL 1 , ' No. Item Top MD Btm MD ID OD . 1 1 Tubing Hanger 27' 31.62' 2 2-7/8"x 1"GLM w/Orifice ±150' ±159' 2.250" 3.680" " % 3• z`, 3 Stage Tool—ES Cementer 2,351' 2,354' 8.618" 9.625" 041 4 2-7/8"x 1"GLM w/Dummy ±4,000' 4,009' 2.250" 3.680" 5 XN Nipple 2.313"/2.205"no-go ±4,175' ±4,176' 2.250" 3.680" 6 ESP Assembly ±4,192' ±4,250' 5.850" ' 7 7-5/8"Tam Port Collar 6,353' 6,356' 6.280" 8 Bullet seal Tie Back 8.66'in TBR 6,414' 6,423' 6.180" 7.350" 9 Liner Top Packer 6,417' 6,432' 7.380" 8.300" ' 10 Swell Packer(2 Total—See Detail Below) See Below See Below 4.892" 8.000" # 4 5-1/2" LINER DETAIL i Jts Top(MD) Btm(MD) length ,14 SOLID 6,443' 6,483' 40' se SLOTTED 6,483' 8,592' 2,109' SOLID 8,592' 8,947' 355' p4. SLOTTED 8,947' 9,603' 656' 111 rr. SWELL PKR 9,603' 9,615' •"r 4 SOLID 9,615' 10,217' 602' SWELL PKR 10,217' 10,233' `, *'� SLOTTED 10,233' 12,248' 2,015' G0,4 ° , SOLID 12,248' 12,639' 391' lit ' SLOTTED 12,639' 13,654' 1,015' 14" f L y 5 ` :1:1:1:1: 1 a A* 14,1 n > , ‘p;'"' .... nM� w 9-5/8"shoe @ .. 6,260' ,- � ,. . 5-1/2"shoe @ 't 7 ►'+i 9 1sc.( 10 1A\ 13,688' • \ vdkz III i v. _8 / \\ ',I1 PBTD=13,690'MD/4,177'TVD ;.k TD=13,690'MD./4,177'TVD Max Deviation:94.89° Revised by TDF 9/28/16 0 ID Milne Point ASR Rig 1 BOPE rtia ;%.1"411,1.11: 11" BOPE Stripping Head 3.98' \ .. .-.. — Shaffer . 4 11"- 5000 Nmilm .pair- fail liti !hilt L. / i ; I 4.54' GCI �••,*U " VBR or Pipe Rams � H Ri I 11"-5000 4 " Blind �.- 11 111 Iiiiii ii 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves -, l , 1LI I _ f 2.00 .) Li��' Ji oiG i , 's 7' 11LIIid11d11 ill'� ' k` Manual Manual Manual HCR Updated 8/19/2015 . • • � �PL_46 Tree Cap. Otis style,5 3/" WELL ACME 2 9-16"5K,FE,DD L-U PN A26299-003 DATE9-17-15 SN H456418 Mil 1 ... m ". Swab valve Seaboard ` Model 510, 2 9/16" 5K, FE,DD L-U `40`` PN 564650-DB1 SN 0100-57293-1-062 ` O � *4"i I 'j Wing valve Seaboard Model 0-6000 510, 2 9/16" 5K, FE,DD L-U I rt.o (k o PN 564650-DB1 SN 0100-57293-1-093 Tbg Hgr,Seaboard SM- ®"p°p E-CL 11 x 2 7/8" EUE BOX top and bottom, 2 SSV valve Seaboard Model 1/2" "H" BPV, ported „ 510,2 9/16" 51(,FE,DD L-U. for 2ea 3/8" Control ` t,7 ®Ir With Safeco 4000 series line,w/4' pup L-U,DD- 0 - actuator, hydraulic NL, For use with Taurus PN 353799 T-57 penetrator system °'` "' SN H456273 PN W12655-001 SNH457680 irn Master valve Seaboard Model I ! L_ ... 510, 2 9/16"5K, FE,DD L-U 9 1,1 PN 564650-DB1 TaurusT57i yl' I c II -. SN 0100-57293-1-091 penetrator,51<v/154 Ll 1 „ �, API 11 5K Amps. PN WT57-F48- e-�ci 3 523-00 'Tot Y I u� fl fitl't-j, 111 PW. 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N I Q o) U_ N >; C o ,I'I w o z cT a 11 1 P I o Co Cl) o IX a reW U • o Z Q N J (1.1 7 o CO CO Om CD C 2o O N p a E ea M N U d I o J E M Q E c)o a I— Ju7 m O r-COZa r CO a ro o W Z < JC11111 • o ll 'rI— O ki, O < Z E D £ 0 , co 1 z o n I co > I' m ✓ I- '6 d N N N N Ce CI (0 0 C• C 1 V w c c U a o R CC) c`> E a O £ p 0 C d d 2 C 0 1 0 • • RECEIVED OCT 15 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'k:onc WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil E - Gas❑ SPLUG LI Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 2OAAc 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 14. Permit to Drill Number/ Sundry: • Hilcorp Alaska, LLC Aband.: ,9/17/2015 ' 215-118 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 •8/17/2015 • 50-029-23551-00-00 4a. Location of Well(Governmental Section): 8. Date TD Reacihed: 'Jac 16.Well Name and Number: Surface: 3303'FSL,4733'FEL,Sec 8,T13N, R10E, UM,AK .9/1?I/2015 • MPL-46 Top of Productive Interval: 9. KB(ft above MSL): •47' 17. Field/Pool(s): 339'FSL, 225'FEL, Sec 7,T13N, R10E, UM,AK GL(ft above MSL): •17' Milne Point Unit/Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1617'FSL, 280'FWL, Sec 16,T13N, R10E, UM,AK N/A ADL 315848,025509, 025515 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 545147.71 y- 6031494.34 Zone- 4 13,690'MD/4,177'TVD N/A TPI: x- 544403.67 y- 6028526.7 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 550226.99 y- 6024562.14 Zone- 4 N/A 1,885'MD/1,864'TVD 5. Directional or Inclination Survey: Yes ❑✓(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) •N/A 22. Logs Obtained: MPL-46: DGR-ADR—EWR-Inverted/Reverted Sections 2"and 5"TVD ROP-DGR-ADR—EWR-Horizontal Presentation 2"and 5"MD MPL-46PB1: DGR-ADR—EWR-Inverted/Reverted Sections 2"and 5"TVD ROP-DGR-ADR—EWR-Horizontal Presentation 2"and 5"MD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 78.6# A-53 Surface 80' Surface 80' 42" 89 bbls 15.6 ppg Stgl L-241 bbls 11.7 ppg 30 bbls T-79.3 bbls 15.8 ppg 9-5/8" 40# L-80 Surface 6,620' Surface 4,174' 12-1/4" Stg 2 L-224 bbls 10.7 ppg 182 bbls T-55.5 bbls 15.8 ppg 7-5/8" 29.7# L-80 Surface 6,423' Surface 4,156' Inside 9-5/8"csg Tieback Assy. 5-1/2" 17# L-80 6,417' 13,688' 4,156' 4,177' 8-1/2" Slotted Linerw Swell Pkrs 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): 2-7/8" 4,253' N/A 5-1/2"Slotted Liner Detail Depths 6,483'-8,592'MD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 8,947'-9,603'MD Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ 10,233'-12,248'MD Per 20 AAC 25.283(i)(2)attach electronic and printed information 12,639'-13,654'MD DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 9/27/2015 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 10/1/2015 24 Test Period . 433 44 105 N/A 101 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 334 0 24-Hour Rate -4. 433 44 105 18 Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 RBDMS�'�'�JOCT 2 02015 Submit ORIGINIAL only 1 28. CORE DATA Conventional C (s): Yes ❑ No ❑✓ Sidewall Corellifes ❑ No ❑✓ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,885' 1,864' Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. SV1 2,189' 2,149' Ugnu MA 4,991' 3,730' Schrader Bluff NA 5,614' 3,984' Schrader Bluff OA 6,368' 4,152' Formation at total depth: Schrader Bluff OA/ 31. List of Attachments: Wellbore Schematic, Days vs Depth, MW vs Depth, Drilling and Completion Composite Reports,Casing and Cementing Reports. Definitive Directional Surveys. Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller@hiICorp.corn Printed Name: Luke Keller / Title: Drilling Engineer Signature: <✓ / Phone: 907-777-8395 Date: -(/2L)/5--- 1(/ 4 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only Milne Point Unit H • • Well: MPL-46 PTD:215-118 SCHEMATIC API: 50-029-23551-00-00 Hilrorp Alaska,LLC RKB:27' CASING DETAIL ,� 1 1 ' Size Type Wt Grade Conn. ID Top Btm 20'""1�i 20" Conductor 78.6 A 53 Weld 19.25" Surf 80' 2 9-5/8" Surf.Csg 40 L-80 TC II 8.835" Surf 6,620' ;1', 7-5/8" Tieback 29.7 L-80 Vam SLIJ-II 6.820" Surf 6,423' 5-1/2" Prod Liner 17 L-80 DWC/C HT 4.892" 6,417' 13,688' ir TUBING DETAIL '' 2-7/8" Tubing 6.4 L-80 EUE 8rd 2.441" Surf 4,253' JEWELRY DETAIL 30 No. Item Top MD Btm MD ID OD 1 Tubing Hanger 27' 31.62' 2 GLM w/Orifice 136' 145' 2.250" 3.680" 3 Stage Tool—ES Cementer 2,351' 2,354' 8.618" 9.625" 4 GLM w/Dummy 4,025 4,034' 2.250" 3.680" 5 X Nipple 2.313"/2.205"no-go 4,176' 4,177' 2.250" 3.680" 6 ESP Assembly 4,195' 4,253' 5.850" 7 7-5/8"Tam Port Collar 6,353' 6,356' 6.280" 8 Bullet seal Tie Back 8.66'in TBR 6,414' 6,423' 6.180" 7.350" 9 Liner Top Packer 6,417' 6,432' 7.380" 8.300" 10 Swell Packer(2 Total—See Detail Below) See Below See Below 4.892" 8.000" 5 1/2"SOLID LINER DETAIL j 5-1/2"SLOTTED LINER DETAIL Jts Top(MD) Btm(MD) Top(MD) Btm(MD) 1 6,443' 6,483' 6,483' 8,592' 4 9 8,592' 8,947' 8,947' 9,603' 15 9,603' 10,233' 10,233' 12,248' 10 12,248' 12,639' 12,639' 13,654' 5 SWELL PACKER DETAIL Top(MD) Btm(MD) :1:11:1: 9,609.02' 9,614.71' istei 10,222.59' 10,228.28' IN • . 9-5/8"shoe @ 111 0 6,260' " A 5-1/2"shoe @ ).7.4 9 �' 1 i� 13,688' 111 8 / PBTD=13,690'MD/4,177'TVD TD=13,690'MD/4,177'TVD Max Deviation:94.89° Updated by CJD 9/29/15 • • Hilcorp Energy Company Composite Report Well Name: MP L-46 Field: North Slope County/State: ,Alaska i(LAT/LONG): evation(RKB): API#: Spud Date: 8/17/2015 Job Name: 1511124D MP L-46 Drilling Contractor AFE#: 1511124D AFE$: $4,137,342 Activity Date Ops Summary 8/15/2015 Nordic 3 released from MP L-49 @1800:Nordic 3 Rig Move from MP L-49 To MP L-46;lay mats,set and install diverter on L-46 with crane 8/16/2015 Continue moving on to L-46.Spot Rig over L-46.;Tighten 21 1/4"Diverter flange.MU Knife Valve&gun barrel.Secure gun barrel.Install 4"ball valves on conductor.;Continue to clean and inspect pits.C/O several suction rubbers.NU 21 1/4"Riser extension. Replace Knife Valve Hyd Lines.Change out lower TDS Hyd drive motor.Change out injectors on Rig Gen#2.;Replace gun tine in Pit#3. Function test Diverter.;Hammer up hardline from stand pipe manifold to Geo Skid,continue with valve repairs in mud pits.Spot and berm up cuttings box.Install flow nipple&fill up line.Secure diverter with chains.;Spot and rig up support shacks,Set Wear ring in Well Head.Load with BHA; 72 jts 5"NC-50 DP&17 jts 5"HWDP,drift and strap.;Reposition drill pipe in the derrick;P/U 72 Jts.of drill pipe out of the pipeshed and rack back in the derrick.;Rig accepted 12:00 Hrs.MPU-L46 8/16/2015 AOGCC Jeff Jones waived to witness test;Hauled 0 bbls to G&I Total Hauled 0 bbls -Hauled 0 bbls to Pad 3 Total Hauled 0 bbls -Hauled 0 bbls to B-50 Total Hauled 0 bbls -Hauled 600 bbls H2O F/L-Pad Lake Total Hauled 600 bbls;-Hauled 516 bbls of H2O FNem Lake Total Hauled 516 bbls 8/17/2015 PJSM.Load BHA components in pipe shed.Load mud products in Hopper room.Spot GYRO Data Unit.Rig up Gyro sheaves.;PJSM,MU BHA with HDBS, QHC1 GRC Tricone Bit,Mud Mtr set @ 1.5 AKO. PU 1 stand HWDP,RIUH and tag fill in conductor(8157'.Fill Diverter stack with water.;Address leak on flow riser and tighten packing on Knife Valve.;Drill and clean out conductor using fresh water to 110'.;Swap to spud mud while drilling ahead.Drill 12 1/4"hole section f/110'to 229'.2-5K WOB,424-450,GPM,525 PSI, 35-40 TD RPM.Circulate hole clean.;POOH standing back HWDP.Pick MWD Tools:8"DM Collar,DGR Collar,EWR- P4 Collar,PWD,HCIM Collar,HOC,UBHO Sub,3 Flex Collars,1 stand HVVD.;Cont drilling 12 1/4"hole from 226'to 467'.Sliding:wob 20-K,456 gpm-1070 psi, 200 psi diff,ROP 250 fph.45 RPM,2500 ft/lbs torq.Rotating:wob 20K,P/U 77K,S/O 77K,ROT 76K. (Vis 190).;POOH with one stand of HWDP and install jars.;Drill down f/467'to 557'and Gyro Survey.;Cont drilling 12 1/4"hole from 557'to 1,114".Sliding:wob 20-K,456 gpm-1478psi,300 psi diff,ROP 102 fph.45 RPM,2500 ft/lbs torq.Rotating:wob 20K,P/U 92K,S/O 88K,ROT 92K. (Vis 178).;Hauled 174 bbls to G&I Total Hauled 174 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls -Hauled 150 bbls H2O F/L-Pad Lake Total Hauled 750 bbls;Hauled 0 bbls of H2O FNem Lake Total Hauled 516 bbls Distance to Plan: 6.12'High 1.93 Left Total=AST 1.80 ART=4.45 8/18/2015 Drill 12 1/4"hole from 1114'to 1682'.Sliding:wob 20-25K,510 gpm-1450psi,260 psi diff,AROP 94.6 fph.80 RPM,2.6kft/lbs torq.Rotating:wob 20K,P/U 110K, S/O 95K,ROT 106K. Mw 9.1,vis 154.;Drill 12 1/4"hole from 1682'to 2247'.Sliding:wob 8-10K,455 gpm-1150psi,80 psi diff,AROP 102.7 fph.80 RPM, 3.5kft/Ibs torq.Rot:wob 4-6K,P/U 126K,S/O 108K,ROT 115K. Mw 9.2,vis 103.;Control drill @ 100 FPH ROP w/450-500 GPM from 2150'to 2250'to assist in hole cleaning prior to Wiper trip. Pump sweeps as needed to keep hole clean.;Circulate Bottoms up.Flow check well.Fill Trip Tank.;POH F/2247'T/431'P/U wt.118k(No significant over pull throughout trip out).;Rig Service.;TIH encountered tight spot 1873'(Base of the permafrost)attempted to work through(No Go)brought pumps up to 450 gpm; orient tool high side;turn pumps off s/o(No Go)brought pumps on and;attempted to wash&ream through 40 rpm 450 gpm.1150 psi.(No Go trying to side track) stopped rotation and orient tool to the exact position that it was drilled turn pumps off and work through;(Good)continued TIH to 2214'encountered 33'of fill; Washed and Reamed to 2247'@ 450 gpm 40 rpms 1300psi.;Continue Dig.12 1/4"section F2247'-T/2935'.Sliding:wob 20/25-K,530 gpm-1550 psi,250 psi diff, ROP 106 fph.80 RPM,4500 ft/lbs torq.Rotating:wob 22K,P/U 140K,S/O 110K,ROT 125K.;Pump a con-dent sweep with walnut plug as a flag brought back 0% more cuttings.;Hauled 1120 bbls to G&I Total Hauled 1294 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 200 bbls H2O F/L-Pad Lake Total Hauled 950 bbls;Hauled 0 bbls of H2O FNem Lake Total Hauled 516 bbls Distance to Plan: 4.73Low 5.9OLeft ART= 6.30 AST= 5.95 • 8/19/2015 Dig f/2928'to 3634'(706')AROP 117.6 FPH Sliding:wob 20/25-K,530 gpm-1750 psi,150 psi diff,ROP 100 fph.80 RPM,5-7k ft/lbs torq.Rotating:wob 15-25K,P/U 121K,S/O 107K,ROT 125K.;Drig f/3634' to 4236'(602')AROP 100.4 FPH Sliding:wob 20/25-K,530 gpm-1850 psi,300 psi diff,ROP 100-130fph.78 RPM,6-8k Nibs torq.Rotating:wob 20-22K,P/U 155K,S/O 105K,ROT 125K.;MW 9.2 Vis 103. Send Sweep at 4130'.;Circulate sweep out of hole.Circulate bootom up from 4236'.;POOH encountered tight spot 4,005'thru 4,113'pulling 35k over, worked through with no pumps(Good)continued POOH to 3205'periodically pulled tight(35 to 40k over)work through with no pumps.;(Good)but the over pull was increasing as we pulled out every stand decision was made to drop down one stand and circ.a B/U.;MU top drive,rotate reciprocate and circulate bottoms up from 3300'505 GPM,1385 psi,4.5-5K ftlbs torque(0 80 RPM.(BU brought back 20%more cuttings);Pulled back to 3205'and the over pull was still there. Discussed with the DD about the geometry of the well and made a decision to back ream out to the last short trip point 2,247'.While back;reaming we encountered differential pressures from the motor 250-600 but no packing off return flow stayed constant.From 2,247'to 1,837'pulled on elevators(Good)but worked through tight spots;spots from the last wiper trip and conditioned them out.;Rig Service.;TIH from 1,837'to 2729(Good)il Depth of 2,729'thru 2765/3,089'thru 3,110'/3,417' thru 3,499'/3,541 thru 3599'.;Attempted to work through(No Go)brought pumps up to 450 gpm 40 rpms 1350 to 1450 psi;orient tool high side and washed down through and back reamed up to open up tight hole.;continue TIH from 3599'to 4232'(No Problems).;Drlg f/4236'to 4295(59)AROP 59' FPH Sliding:wob 20/25-K,530 gpm-1850 psi,300 psi diff,ROP 100-130fph.78 RPM,6-8k ft/lbs torq.Rotating:wob 20-22K,P/U 155K,S/0 110K,ROT 125K.;Hauled 996 bbls to G&I Total Hauled 2290 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 1350 bbls H2O F/L-Pad Lake Total Hauled 2300 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 516 bbls Distance to Plan:2.34 Low 43'Left ART=7.20 AST2.19 8/20/2015 DrIg f/4295'to 4687'(392')AROP 65.3' FPH Sliding:wob 8/10-K,560 gpm-1780 psi,2-300 psi diff,ROP 100-130fph.80 RPM,7-9k ft/lbs torq.Rotating:wob 6-12K,P/U 165K,S/O 107K,ROT 124K.;MW 9.2, Vis 120.;Drig f/4687'to 5175' (488')AROP 44.4 FPH. Sliding:wob 12/16-K,563 gpm-1880 psi,2-300 psi diff,ROP 200-250fph.80 RPM,8-9k ftlbs torq.Rotating:wob 15-22K,P/U 165K,S/0 107K,ROT 124K.;MW 9.2,Visc 104. Experiencing periodic motor stalls.; Formation:Ugnu/LC2.Pumped 20 bbls Drill N Slide Lube Pill @ 4825'. Bring active up to 1%Lube. Sliding ROP increasing.;POOH F/5,175'-T/4,120' (No problems to report during trip out);Rig service;TIH 4,120'-T/5,082';Fill pipe and wash down to 5,175'(No problems to report on trip in);Drig f/5175' 5398'(223)AROP 45 FPH Sliding:wob 12/20-K,559gpm-1880 psi,175/250 psi diff,ROP 45-250fph.80 RPM,8-9k ft/lbs torq.Rotating:wob 15-22K,P/U 168K,S/O 110K,ROT 125K.;Hauled 812 bbls to G&l Total Hauled 3102 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 205 bbls H2O F/L-Pad Lake Total Hauled 2505 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 516 bbls Distance to Plan: 11.10 High .69'Left ART=4.29 AST=7.27 8/21/2015 Drig f/5398' 5686'(288')AROP 48 FPH. Sliding:wob 15/20-K,592 gpm-2020 psi,150/200 psi diff,ROP 80-100 fph.80 RPM,9-10k ft/lbs torq.Rotating:wob 20-28K,P/U 183K,S/0 107K,ROT 138K.;MW 9.2,Visc 120 Maintaining 1%Lube.;Drig f/5686' 5817'(131')AROP 52 FPH. Sliding:wob 15/20-K,592 gpm-2020 psi,150/200 psi diff,ROP 80-100 fph.80 RPM,9-10k ft/lbs torq.Rotating:wob 20-28K,P/U 183K,S/0 107K,ROT 138K.;Last slide was from 5739'to 5804' rQ 72 fph with no issues. Started rotating from 5804'to 5817'(13')ROP fell from 27 fph to 6 fph with 25-28 WOB.Diff fell from 250 to 40.No substantial change in pump pressure.;TOH for bit from 5817'to 4200'with no issues.Hole in good condition.PU Wt 195-200K,SO 112K.Hole fill took 2 bbls over calculated. Pump Slug 4200'. Continue to TOH F/4200'.741'(BHA).;BHA:Racked back 8"collars and and broke off the bit(Number 3 cone bearing on loose).;Clean off floor-Monitor Well- Static Loss Rate 1.5bph;TIH with BHA to 700'-1 joint of NMFIex DC and the UBHO had to be laydown due to damage on the facing and treads;Rig up&Slip and cut off 65'+/-drilling line;Continue TIH t 805';Hauled 976 bbls to G&I Total Hauled 4078 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 415 bbls H2O F/L-Pad Lake Total Hauled 2920 bbls;Hauled 0 bbls of H2O FNem Lake Total Hauled 516 bbls Distance to Plan:5.88'High 11.07'Right AST=5.91 ART=2.5 • • 8/22/2015 Finished Slip and cut drill line. TIH from 800'to 2800'.;Fill pipe,break circulation and perform 4 MWD Survey Check Shots.;Continue to TIH on elevators from 2800'to 4970'with no issues.;Fill pipe,break circulation and perform 4 MWD Survey Check Shots.;Continue to TIH on elevators from 4970'to 5209'.Set down in tight spot @ 5209'.Work up to top of stand with 30-35k over pulls.;Wash and ream to from 5209'to 5790'.Started taking Wt @ 5790'Wash and ream under gauge hole from 5790'to TD @ 5808'.;DrIg f/5808' 6060'(252')AROP 42 FPH. Sliding:wob 15/20-K,530 gpm-2020 psi,150/200 psi diff,ROP 80-100 fph.80 RPM,9-10k ft/lbs torq.Rotating:wob 20-25K,PN 183K,S/O 107K,ROT 138K.;MW 9.4,Vis 120.Pump 20 bbls lube pill at 6020';Drlg 1/6060't/6428'(368)AROP 31 FPH. Sliding:wob 15/20-K,555 gpm-1850 psi,150/200 psi diff,ROP 20-80 fph.80 RPM,9-10k ft/lbs torq.Rotating:wob 20-25K,P/U 175K,S/0 102K,ROT 130K.;MW 9.4,Vis 120.Pump 30 bbls lube pill at 6410'.;Hauled 618 bbls to G&I Total Hauled 4696 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 300 bbls H2O F/L-Pad Lake Total Hauled 3220 bbls;Hauled 0 bbls of H2O FNern Lake Total Hauled 516 bbls Daily Fluid Loss-36bb1. Total-36bb1. Distance to Plan:12.39'Low 29.86'Right AST=7.53 ART=2.68 8/23/2015 DrIg f/6428'V6630'(368)AROP 31FPH. Sliding:wob 20/25-K,457 gpm-1490 psi,200/270 psi diff,ROP 150-200 fph.80 RPM,6-10k ft/lbs torq.Rotating:wob 20-25K,P/U 185K,S/O 105K,ROT 130K.;MW 9.3+Vis 70.Max Gas @ 240 units.Reached initial casing point in the Upper OA sand at 6428'MD.Drilled extended TD an additional 202'for pump tangent and liner lap to 6630'.;Started Pump Tangent @ 6313'to 6630'(317')(10'rat hole 6620')(100'Liner Lap 6520')(Total Pump Tangent 6313'-6520'(207'). Last survey:MD 6583.53,Inc 86.42,Azi 123.04.;Projection @ the Bit:6630'MD,88.29 Inc,122.69 Azim,TVD 4175.Distance to plan 13.3'Low,24.3'right.;Stand back 1 stand to 6550'.Circulate bottoms up @ 600 GPM 1950 psi.Max gas @ 314 units.;Short trip from 6550'to 5600'195K Up Wt w/no pump.Attempt to work through tight spot at 5940'.Kelly up and Back ream f/5975'-5890'.Continue Short trip V5600'on elevators w/no issues.;TIH from 5600'to 6550'.SO Wt 105K no pump.MU TD,fill pipe and establish retums.Come down on pumps,RIH and tag bottom w/no pump or fill @ 6330'Bring on pump and wash to 6550',set back 1 stand.;Circulate and condition hole surface to surface x2 for casing run.Lower vis from 120 in to 60 in with 9.4 MW in/out and YP @ 30.;TOH on elevators from 6550'to 5690'with no issues.Slug Pipe and continue to TOH from 5690'to 709'.;BHA-Rack HWDP&Jars in derrick-Down load MWD-UD Bit,Motor and MWD.;Clean off floor-pull out BHA out of pipe shed-wash stack and pull wear ring.;Make dummy run with 9 5/8 hanger-Rig up to run 9 5/8 casing.;PJSM-PN shoe track and check floats(Good)TIH with 9 5/8 surface casing.;Hauled 696 bbls to G&I Total Hauled 5392 bbls Hauled 0 bbls to Pad 3 Total Hauled 0 bbls Hauled 0 bbls to B-50 Total Hauled 0 bbls Hauled 600 bbls H2O F/L-Pad Lake Total Hauled 3820 bbls;Hauled 0 bbls of H2O FNem Lake Total Hauled 516 bbls Daily Fluid Loss-36 bbl. Total Fluid Loss-72 bbl Distance to Plan:15.27'Low 25,85'Right AST=.70 ART=2.29 8/24/2015 PJM with Rig and Casing Crew.Run 9 5/8"47#L-80 TC-II csg as follows: Float Shoe 1 Shoe Jt(w/2 cent 10'each end) Float Collar(W/By Pass BFL) 1 Jt(w/2 cent 10'each end) Pup Jt BFL Adapt. PupJt;103 jts Pup JT ES CMTR Pup Jt 57 jts Pup jt Casng Hanger.;Details:Filled casing every 500',broke circulation every 1000'circulating 20-30 bbls. Placed centralizers on couplings 5 jts before and 5 jts after ES Cementer.;Pick up landing Jnt.and hanger and land. Break circ.one B/U with the CRT @ 2bpm easing rate up to 6bpm beg.psi.875 ending 350psi.While reciprocating pipe P/U 325k S/O 75k.;Start to pump,but could not reciprocating pipe @ 5bpm stating 500psi Ending 395psi.;PJSM-Batch up cement-Turn over to Halliburton. Pump 10 bbls water&test lines to 3500 psi. Good.Start pumping 60 bbls of 10.5 mud push @ 4bpm. • • 8/25/2015 PJSM with Haliburton Cementers. Perform cmt job as follows: Pump 5 bbls FW,Pressure test lines to 3500 psi, Pump 60 bbls of spacer at 10.5 ppg @ 4 BPM,Drop by pass plug w/last 2 bbls spacer.;Shut down and load shut off plug. Mix and pump 549 sxs(241 bbls)of class G cement at 12.0 ppg. Mix and pump 387sxs(79 bbls)of class G cement at 15.8 ppg. Drop Shut off Plug.;Displace cmt w/20 bbls FW f/Cmt Unit,tum over to rig,pump 245.5 bbls,9.4 ppg Mud,pump 80 bbls FWf/cmt unit,tum over to rig,pump 132 bbls Mud. Bump plug with 500 psi over final circulating pressure. Bleed off pressure with 1.5 bbls back. Floats held.;Cement unit stage pressure up 2700 psi to open ES Cementer.No open.Bleed down to 1000 psi,hold for 5 min,step pressure up to 2850 psi and shear open ES Cementer.Circ 10 bbls FW f/cmt unit.;Tum over to rig,circulate bottoms up bringing 60 bbls spacer and 30 bbls+/-of cement to surface.;Details: Full retums through out job. Pump Cement @ 3 BPM Average. Pump Displacement @ 5 BPM Average.Calculated Displacement 477 bbl,Actual Displacement 469 bbl.;Final circulation pressure 1300 psi,CIP @ 10:09.;Continue circulate through ES Cementer while prepping for 2nd stage Cement job.;PJSM, shut down&closing plug. Swap over to cmt unit.;Mix&pump 60 bbl of Tuned Spacer III 10.5 PPG. Swap to Lead,Mix&Pump 223 bbl @ 10.7ppg Lead. Mud push observed at the shakers.Divert to diverter box.;Swap to tail, Mix&pump 46 bbls of 15.8 ppg.Drop closing plug,pump 10 bbl on top of plug&chase with 20 bbl of H2o. Swap to rig&displace with 9.3 ppg mud @ 5 bpm.;Slow down pump to 2 bpm @ 142 bbl&bump plug @ 146 bbl away. (6 bbl early) Final lift presure @ 650 psi @ 2 bpm. Pressure up to 2000 psi&shift ES cmt tool.Hold for 5 min. Bleed off 1.25 bbl.;No flow.Good. ' Total cmt returned to surface 182 bbl+60 bbl spacer. 650 Final lift presure. Cmt In Place©18:57 hrs;R/D haliburton&flush stack and lines.;Pull landing jt.Flush debris from top of hanger,M/U and set casing hanger packoff per Hilcorp wellhead rep,RILDS.;N/D Diverter system,R/D and cleanout diverter line.Continue to clean pits.Welder repair hopper feed line in pill pit and pit 4,;N/U seaboard tubing spool,install packoff-9 5/8"P-seals. Notified AOGCC of upcoming BOP test.;-Hauled 928 bbls to G&I,total=6668 bbls -Hauled 75 bbls to Pad 3,total=145 bbls -Hauled 465 bbls H2O F/L-Pad Lake,total=4585 bbls -Hauled 0 bbls of H2O FNern Lake,total=516 bbls 8/26/2015 N/U Multi Bowl&Atempt a test on the void. Flange leaking at ring groove. Remove multi bowl&change API ring.Clean groove&install same.Test to 250/3000 psi.Good.;Clean pits,replace suction line in pill pit.;N/U BOPs. Install riser. Clean&organize cellar. Work on installing new water transfer pump.;Continue to N/U BOPE,R/U mud cross lines,flow line.Rig Electrician calibrate and test gas alarms.Continue to clean pits,Load BHA 3 into pipe shed.;R/U test equipment using 5" test jt,fill stack and lines with water,shell test BOPE to 3000 psi,witness waived by AOGCC rep J.Hill on 8-26-15 @ 12:45 hrs.Test BOPE per AOGCC state requirements.;Test Blind ram,lower 5"pipe ram,upper and lower IBOP,FOSV,dart valve,mud cross valves,choke man valves and annular to 250/3000 psi 5 min ea.charted.;Attempt to test upper 2 7/8"x 5"VBR,not holding on low pressure test,troubleshoot leak,upper VBR leaking by.;Drain stack, LOTO accumulator, open ram doors,inspect and C/0 VBR packers and upper seals,reinstall VBR.Attempt re-test,will not hold.Decision made to install 5"rams,pull VBR.;-Hauled 754 bbls to G&I,total=7422 bbls -Hauled 0 bbls to Pad 3,total=145 bbls -Hauled 50 bbls H2O F/L-Pad Lake,total=44635 bbls -Hauled 0 bbls of H2O FNem Lake,total=516 bbls 8/27/2015 Finish changing top VBR5 to 5"rams.;Test top rams to 250/3000 psi.Good.Perform accumulator test. Good.;R/D testing equipment.Set WB.R/U 5"handling equipment.;P/U BHA#3, 8 1/2 Bit,GEO Pilot 7600 EDL,Stab,REF Housing,DGR Collar,PWD,Smart Stab,ADR,DM,TM,Float Sub,3 NMFC,1 HWDP,Jars,7 Joints HWDP. Uploaded tools.Good.;L/D 9 Uneeded Joints of HWDP.;RIH P/U NC 50 DP F/459'T/2074'.Tag CMT Stringer.;Wash&Ream @ 40 RPM 450 GPM 1250 PSI.3-5k WOB F/2074'T/2330'.Tagging hard CMT,drill CMT to 2349'tagging plug above ES cementer;Drill plugs and ES cementer from 2349'to 2352'reaming to 2360'pumping 450 gpm,1180 psi,WOB 3-5K,40 rpm,torq 1500-3000 ft/lbs, backream thru ES cementer 4 times cleaning up,drift same.;Note: plug rubber observed @ shakers.;Single in the hole with NC50 DP f/2367'to 2380'w/10K setdown,M/U topdrive,wash and ream cleaning cmt stringers and debris f/2380'to 2410'pumping 454 gpm,1183 psi,60 rpm,3-5k WOB.;Continue to single in with NC50 5"DP from 2410'to 3215'(88 jts total).;TIH with 24 stds from 3215'to 4658',note:UD 4 marked bad jts on last 4 stds ran,correct displacement on TIH.;;Hauled 53 bbls to G&l,total=7475 bbls -Hauled 0 bbls to Pad 3,total=145 bbls -Hauled 300 bbls H2O F/L-Pad Lake,total=4935 bbls -Hauled 0 bbls of H2O FNem Lake,total=516 bbls 8/28/2015 .P/U DS-50 5"DP F/4658'T/6300'.Tag Cmt Stringers.;Drill Cmt Stringers F/6300'T/6527'.Tag baffle adaptor plug.;Circ btm up.;Test casing to 3000 psi for 30 min. Bled down 50 psi in 30 min. Good test.;Drill BFL Plug&Adaptor F/6527'T/6530'@ 5-15K WOB,400-550 GPM 40-50 RPM. Drill cmt F/6530'T/6582'@ 40 RPM 525 GPM 1800 PSI. Tag FC @ 6582'.;Drill FC,CMT to shoe @ 6618'exiting shoe @ 6620'.Drill @ 425 GPM 1400 psi 40-60 RPM 9-10k Torque., cleanup rathole and drill 20'of formation to 6650';Wth existing 9.25 ppg mud in good shape,R/U and Perform F.I.T to 12 ppg EMW.Good Test.;PJSM,pump 25 bbl hi vis sweep,Displace to 8.9 ppg new BARADRIL mud pumping 6.7 bpm,700 psi,rotate 20 rpm and reciprocate.Sweep back on time w/100%increase in sand:and several large pieces of plug rubber,with good 8.9 ppg mud in/out set back 1 std and park @ 6575',flowcheck well,static.;Monitor well,install FOSV,cut and slip 45'drilling line,re-set and test crown saver while cleaning pits 1&2.;Service top drive,swivel,blocks and crown while cleaning pits and installing 170# shaker screens.;Finish cleaning pits 1&2,equalize pit volume.P/U 225K,S/O 87K,ROT 130K.60 rpm torq off 9500 ft/Ibs;M/U stand,obtain parameters,drill 8 1/2"hole f/6650'to 6747'pumping 520 gpm,1650 psi,WOB 7-10K,rotate 60 rpm, torq 11500 ft/lbs.60/80 fph,ROP slowing to 1-2 fph. Note:1680u gas @ 6740';P/U off bttm,increase to 100 rpm,torq 12500 ft/lbs.Drilling from 6747'to 6750'@ 1-2 fph,WOB 10k,ROP increased f/6750'to 6759' then slowing to 1.5 fph. Suspect siderite formation.;Continue drilling thin hard formation f/6759'to 6764'@ 1.5 fph then ROP increasing to 75/100 fph,continue drilling f/6764'to 6840'.;P/U 220k,S/O 80k,ROT 130k.MW 8.9 ppg,vis 40.ECD 9.66 ppg.BGG 40u.No losses.;13.45'below the line and 24.29'right of the line.;- Hauled ine.;Hauled 406 bbls to G&I,total=7881 bbls -Hauled 0 bbls to Pad 3,total=145 bbls -Hauled 85 bbls H2O F/L-Pad Lake,total=5020 bbls -Hauled 557 bbls of H2O FNem Lake,total=1073 bbls • • 8/29/2015 Drill Ahead F/6840'T/6920'(80'@ 40 FPH) 10-15 WOB 13K TO 535 GPM 1700 psi 80-100 RPM Still Hitting Hard stringers;TD Started leaking HYD fluid. Stand back stand 1/6865'. Troubleshoot TD. Determined that Relief valve popped when TD stalled. TIH&Continue Drilling.;Drill ahead F/6920'T/6935'. 10-15 WOB 13K TO 535 GPM 1700 psi 80-100 RPM;Hit Hard spot @ 6935'Drilled T/6940'. Try WOB 5-25K. RPM 50-100. Worked pipe. Lowered pump rate to 430. Changed tool deflection and it did not change ROP.;POOH F/6940'T/6620'inside 9 5/8"csg,flowcheck well,static.Pump dry job,continue to POOH to 459',Rack HWDP,jars and remaining BHA in drk.Inspect tools,L/D bit,grade=1,2,CT,A,X,I,NO,PR.;1.2 bbls over calculated displacement on trip out of the hole.Note:found 2 pieces of alum.3/4"thick x 2 1/2"wide including copper spring wedged in top of GEO-steer sleeve.;M/U BHA#4,8 1/2"MM65M PDC bit and NBS,TIH with directional tools,jars and HWDP to 460',TIH to 6585' (fill pipe @ 3280',test MWD and GEO-steer);Fill pipe @ 6585',M/U 2 stds RIH to 6775',M/U top drive,set topdrive in high gear,test same @ 100 rpm w/14k torq,120 rpm w/16.7k torq.TIH to 6873',wash&ream to bttm @ 6940'w/no fill.;14 bbls under calculated displacement on TIH,In high gear w/top drive reaming to bttm,120 rpm,torq 17k,drill string violently shaking,resume w/top drive in low gear. P/U 225K,SIO 80K,ROT 125K;Continue drilling 8 1/2"hole from 6940'to 6999'pumping 529 gpm,1700 psi,WOB 5k,100 rpm,torq 13000 fibs,ROP 120 fph, MW 8.9 ppg,vis 41,seepage while drilling @ 6 bph. Note:106u gas @ BU;Hard drig f/6999'to 7001'drilling thru siderite formation,ROP increasing to 120/150 fph di-1g to 7245'pumping 529 gpm,1720 psi,WOB 5- 8k,80 rpm,12000 ft/lbs torq, P/U 205K,SIO 75K,ROT 125K.;Obtain SPR @ 7054'.Pump 25 bbl lo vis sweep @ 7200'.MW 8.9 ppg,vis 40,ECD 9.83 ppg.Seepage reducing to.6 bph while drilling.;13.03'above the line,1.32'left of the line;Daily fluid loss-96 bbls Total fluid loss-206 bbls;-Hauled 764 bbls to G&I,total=8645 bbls -Hauled 0 bbls to Pad 3,total=145 bbls -Hauled 425 bbls H2O F/L-Pad Lake,total=5445 bbls -Hauled bbls of H2O FNem Lake,total=1073 bbls 8/30/2015 Drill Ahead F/7200'T/'8190' (990'(42 82.5 FPH) 8-15 WOB 13K TQ 530 GPM 1832 psi 80-100 RPM Hard spot 8107'T/8117'.10-15 FPH.;Drill F/8190'T/'8344' (154'@ 26 FPH) 8-17 WOB,14K TQ,P/U 220K,S/O 80K,ROT 120K 543 GPM 1930 psi,MW 9.1,vis 39,ECD 9.9 ppg 85 RPM Hard spots 8260'T/8265'@ 10 FPH,8335'-8342'@2 FPH;Drill Ahead F/8344'T/'8535'(191'@ 32 FPH) 9-12 WOB,13K TQ,P/U 225K,S/O 70K,ROT 125K 535 GPM 1900 psi, 85 RPM Hard spots 8427'to 8436'@ 3-8 FPH,8528'to 8535'@ 1-6 FPH;Note:pump low vis sweeps @ 7200'and 8110',sweeps back on time with minimal increase SPR @ 8470',MW 9 ppg,vis 36,ECD 9.88 ppg.BGG 70u. Note 10 bph seepage starting @ 8527';11.44'below the line,2.63'left of the line.;Daily fluid losses=20 bbls total fluid losses=226 bbls;-Hauled 348 bbls to G&I,total=8993 bbls -Hauled 290 bbls to Pad 3,total=435 bbls -Hauled 380 bbls H2O F/L-Pad Lake,total=5825 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 8/31/2015 Drill Ahead F/8535'T/8564'. Working through bones @ variable RPM,GPM&WOB. Not Helping. 40-130 RPM,430-550 GPM,5-20 WOB. Hard spots 8535'-8537'. 8546'-8549'. 8563'-8564'. 1-2 FPH;Slow ROP.Monitor well,Pooh F/8564' T/7800'.20-50k Bobbles. Off btm 250K UP/75K DN Had to Kelly up and backream F/8250'TI 8184'.;Pulled tight&no room to break over going down. No over pull while backreaming. Continue to POOH F/7800 T/ 6620'. Clean.Hole taking the proper flll.;Pump Dry job. Test TD @ high RPM. POOH F/6620'to HWDP @ 460',flowcheck well,static.Rack HWDP,jars and remaining BHA in drk.Inspect tools,UD bit,grade=1,1,CT,A,X,I,NO,PR;Note:6.6 bbls over calculated displacement on trip out.Static loss rate 1.5 bph.;M/U new 8 1/2"VM-3 mill tooth bit,RIH with BHA#5 directional tools,jars and HWDP,RIH w/52 stds NC50 DP f/460'to 5401',single in w/39 jts DS50 DP to 6583'filling pipe @ 3200'and 6583'.;Note:2.7 bbls under calculated displacement on trip to shoe.;Monitor well,M/U FOSV,cut and slip 45'drilling line,re-set and test crown saver.;Service top drive,blocks and crown.Inspect drawworks brakes.;12.34'below the line,3.99'left of the line.;Daily fluid losses=67 bbls total fluid losses=273 bbls;-Hauled 464 bbls to G&I,total=9457 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 600 bbls H2O F/L-Pad Lake,total=6425 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/1/2015 Parked @ 6581'.Service Top Drive and Blocks.;Continue to TIH from 6581'to 8470'. Wash and Ream f/8470'to 8564'.525 GPM,1800 psi,60 rpm-120 Rot,10K free TQ;DrIg f/8564'to 8661'(97')AROP 32 FPH. WOB 10/25-K,525 gpm-2000 psi,100/160 psi diff,ROP 30-50 fph.80 RPM,11-12k ft/lbs torq.P/U 165K,S/O 95K,ROT 125K.;Crossed first fault @ 8645'with 15 to 25 bph Iosses.;Drig f/8661' to 8905'(244')AROP 40.6 FPH. WOB 25/30K,534 gpm-2000 psi,130/170 psi diff,ROP 80-100 fph.80 RPM,11-12k ft/lbs torq.P/U 165K,S/O 95K,ROT 125K.;Drig f/8905'to 9097'(192') AROP 32 FPH. WOB 25/30K,534 gpm-2000 psi,130/170 psi diff,80 RPM,13-14k ft/lbs torq.P/U 160K,S/O 95K,ROT 125K. MW 9.1 ppg,vis 39.ECD 10.07 ppg.;Note:Pumped 15 bbl tandem to vis sweep @ 8931',sweep back on time w/minimal increase.;Drlg f/9097'to 9140'(43') AROP 7 FPH. WOB 25/30K,534 gpm-1950 psi,120/160 psi diff,80 RPM,13.5-15k ft/lbs torq.P/U 165K,SIO 90K,ROT 120K. MW 9.1 ppg,vis 37.ECD 10.08 ppg.;Note:very hard drilling f/9096'to 9098'and currently @ 9140' 5 bph seepage while drilling.;13.18'below the line,0.99'left of the line.;Daily fluid losses=84 bbls total fluid losses=357 bbls;-Hauled 232 bbls to G&I,total=9689 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 150 bbls H2O F/L-Pad Lake,total=6575 bbls -Hauled 0 bbls of H2O FNern Lake,total=1073 bbls • 9/2/2015 TOH for Bit from 9141'to 6582'. Pu 195K no pump.;Monitor well for losses with static loss rate @ 1.5 BPH. Pump slug;Continue to TOH from 6582'to surface.Break off and UD and Grade Bit @ 2-1-WT-A-E-I-NO-PR Note 3.7 bbls over calc disp on trip out;Plug in and down load MWD Data.Check oil level in Geo Pilot to verify upper and lower seals are holding.all good.Change out TM Collar. MN Reed 8.5"SK616M-J1D Bit. Plug in and up load MWD.;TIH with BHA#6 to 460',continue to TIH 1/460'to 9040'filling pipe @ 2830'and 6618',wash and ream last std and single to bttm,no fill, get parameters. Note:correct disp on trip in.;Drill 8 1/2"hole f/9140'to 9157'(17')AROP 11 FPH. WOB 4-10K,532 gpm-2080 psi,60 RPM,11200k ft/lbs torq.P/U 175K,S/O 85K,ROT 120K. MW 9.2 ppg,vis 38.ECD 10.14 ppg;Note:Follow concretion drig strategy when encountering concretion stringers. 837u gas @ BU.;Drill 1/9157'to 9573'(416')AROP 69 FPH. WOB 10-35K,530 gpm-2020 psi,60-80 RPM,10500k Nibs torq.P/U 165K,S/O 90K,ROT 125K. MW 9.2 ppg,vis 38.ECD 10.17 ppg;Note:4 bph seepage while drilling 13.32'below the line,2.96'right of the line;Daily fluid losses=37 bbls total fluid losses=394 bbls;-Hauled 406 bbls to G&l,total=10095 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 300 bbls H2O F/L-Pad Lake,total=6875 bbls -Hauled 0 bbls of H2O FNern Lake,total=1073 bbls 9/3/2015 Drill f/9573'to 10178'(605')AROP 100.8 FPH. WOB 10-30K,545 gpm-2174 psi,95-100 RPM,10500k Nibs torq.P/U 163K,S/O 82K,ROT 124K. MW 9.2 ppg,vis 38.ECD 10.6 ppg;Note:Crossed Faults @ 9390'and 9690'. Note:Follow concretion ddg strategy when encountering concretion stringers.;Drill 1/10178'to 10590'(412')AROP 137.3 FPH. WOB 10-30K,545 gpm-2054 psi,95-100 RPM,9.5-10.5k ft/lbs torq.P/U 163K,S/O 82K,ROT 124K. MW 9.2 ppg,vis 38.ECD 10.6 ppg;Drilling Concretions f/10590'to 10,600'and 1/10605'to 10609' WOB 30-40K,530 GPM,40-60 RPM,12-14.5 TQ,;Drill 1/10609'to 11049'(440')AROP 73 FPH. WOB 10-30K,545 gpm-2054 psi,95-100 RPM,9.5-10.5k ft/lbs torq.P/U 185K,S/O 75K,ROT 118K. MW 9.2 ppg,vis 38.ECD 10.54 ppg;Drilling Concretions 1/11049'to 11085' WOB 30-40K,531 gpm-2100 psi,30-60 RPM,12-15k ft/lbs torq MW 9.1 ppg,vis 38.ECO 10.1 ppg;Note:Pump tandem lo vis sweeps @ 10170'and 10936',sweeps back on time w/no increase. Currently 7 bph seepage while drilling. 31.13'below the line,2.31'right of the line.;Daily fluid losses=172 bbls total fluid losses=566 bbls;-Hauled 1044 bbls to G&I,total=11139 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 600 bbls H2O F/L-Pad Lake,total=7475 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/4/2015 Drilling Concretions 1/11085'to 11105'(20')AROP 3.1 FPH WOB 30-40K,531 gpm-2100 psi,30-80 RPM,12-20k ft/lbs torq MW 9.1 ppg,vis 38.ECD 10.1 ppg;Started drilling Concretion @ 11050'to 11105'(55')(12.5 hrs)AROP 4.4 FPH;Drill 1/11105'to 11495'(390')AROP 70.9 FPH. WOB 10-25K,535 gpm-2140 psi,95-100 RPM,12-13k ft/lbs torq.P/U 150K,S/O 115K,ROT 118K. MW 9.1 ppg,vis 38.ECD 10.40 ppg.;Drill Concretions 1/11341 to 11345'. 11,445'to 11,495'. Drill hard spots with 20-30K WOB,80-95 RPM;Drill 1/11495'to 11722'(227')AROP 37.8 FPH. WOB 10-25K,535 gpm-2140 psi,95-100 RPM,12-13k Nibs torq.P/U 150K,S/O 115K,ROT 118K. MW 9.2 ppg,vis 40.ECD 10.42 ppg;Drill f/11722'to 11817'(90)AROP 16 FPH. WOB 5-25K,530 gpm-2130 psi,95-100 RPM,12-16k ft/lbs torq.P/U 150K,5/0 115K,ROT 118K. MW 9.2 ppg,vis 39.ECD 10.35 ppg;Drill Concretions 1/11722'to 11725',11748'to 11749',11754'to 11768' Drill hard spots with 20-30K WOB,80-95 RPM;Note:average loss rate increasing to 23 bph while drilling,increase LCM background V 17 ppb to 25 ppb. 37.56'below the line,29.78'left of the line.;Daily fluid losses=229 bbls total fluid losses=795 bbls;-Hauled 982 bbls to GM,total=12067 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 1200 bbls H2O F/L-Pad Lake,total=8675 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/5/2015 Drill 1/11,817'to 11,958'(141')AROP 26.6 FPH. WOB 5-25K,530 gpm-2130 psi,95-100 RPM,12-16k ft/lbs torq.P/U 190K,S/O 115K,ROT 125K. MW 9.2 ppg,vis 39.ECD 10.35 ppg.;Drill hard spots @ 2-4 FPH AROP with 20-30k WOB,90 RPM,16-18K TQ.;Drilled down all DP in Derrick to 11,958' TOH on elevators from 11958'to 8945'.Pu WI on btm,no pump 230K.SO 145K. Work through tight spots on elevators @ 11'398',11,304',w/40-50K Wt Swings.;Pull through Faults @ 9690'and 9390'with no issues.Hole fill took 1.5 bbls over calculated. Note:Spike Mud Volume @ surface to 2%Lube by adding 1%NXS Lube.;TIH 1/8945'picking up 17 jts HVVDP&1 sgl DP.TOH standing back HVVDP(Push Pipe).TIH P/U 30 jts 5"DS-50 DP f/8945'to 9983'. Having issues stacking Wt.;M/U Top Drive,fill pipe,Rotate,Reciprocate pipe while circulating Surface to Surface,displacing hole with 2%Lube mud from pits.Torque decreased from 8.9k to 6.8k,Up wt decreased f/140K to 130K,;S/0 Wt 90K w/pump no Rot, S/0 90K no pump, P/U 170K w/pump no Rot,P/U Wt 175 no pump.Hole unloaded @ Btm Up w/100%increase in real fine sands.;Continue TIH P/U 18 additional jts DS-50 DP from 9983'to 10,455'.TIH w/HWDP t/11,017'. TIH w/stds f/derrick U11,300'. Started taking W1,attempt work down with no success. Correct disp on TIH;Wash and Ream from 11300'to 11780',500 gpm,1800 psi,35 rpm,9k TQ. #2 MP releif valve tripped during a connection due to hydraulic pump not on that operates Hyd IBOP.;Attempt to reset#2 MP relief valve,stem broke on valve, rebuild relief valve and test.#1 MP relief valve leaking,rebuild and test same.;Continue to wash and Ream from 11780'to TD @ 11958'with no fill on bttm.;Drill concretions 1/11958'to 11963' WOB 10-30K,530 gpm-2180 psi,60-90 RPM,11-13k ft/lbs torq.P/U 195K,5/0 80K,ROT 133K. MW 9.2 ppg,vis 39.ECD 10.25 ppg.;Note:pump 20 bbl sweep w/2%NSX lube around @ 11963',sweep back on time w/50%increase in sand.;Drill 1/11,963'to 12,053'(90')AROP 36 FPH. WOB 5-25K,530 gpm-2150 psi,95-100 RPM,11-12k ft/lbs torq.P/U 195K,5/O 80K,ROT 133K. MW 9.2 ppg,vis 39.ECD 10.27 ppg.;Loss rate while drilling @ 14 bph. 28.71'below the line,38.20'left of the line.;Daily fluid losses=214 bbls total fluid losses=1009 bbls;-Hauled 464 bbls to G&I,total=12531 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 300 bbls H2O F/L-Pad Lake,total=8975 bbls -Hauled 0 bbis of H2O FNem Lake,total=1073 bbls • ! 9/6/2015 Drill f/12,053'to 12195'(142')AROP 21.8 FPH. WOB 5-25K,530 gpm-2150 psi,40-65RPM,11-12k ft/lbs torq.P/U 195K,S/O 80K,ROT 133K. MW 9.2 ppg,vis 39.ECD 10.27 ppg;Encounter hard drilling streaks with fast drilling breaks between hard spots @ 100-250 FPH. Drill hard spots @ AROP 2-3 FPH with 20-30k WOB,40-90 RPM,13-15K TQ. Adjusting parameters as needed. Drilled on hard streak that caused excessive dog leg that was identified by At Bit Inclination.Deflected from 91 deg to 85 deg Inclination in 20';Pull up hole to 12,110'.Begin Open hole low side side track operations,troughing from 12,110'to 12,151'. 550 GPM,2160 SPP,100 RPM-13K Tq,WOB 2-16K.;Drill f/12,151'to 12,215'(64')AROP 10.6 FPH. WOB 5-25K,505 gpm-1950 psi,40-65RPM,10-12k ft/lbs torq.P/U 205K,S/0 80K,ROT 135K. MW 9.2 ppg,vis 39.ECD 10.27 ppg.;Note:15 bph loss rate average diminishing to no Iosses.;Drill f/12,215'to 12,526'(311')AROP 51.8 FPH. WOB 10-25K,505 gpm-1950 psi,40-65RPM,12-16k ft/bs torq.P/U 205K,5/0 75K,ROT 135K. MW 9.1 ppg,vis 39.ECD 10.21 ppg.;Geopilot ABI(At bit inclination lost calibration)sending inaccurate readings.troubleshoot same with no success,take final survey,get SPR. Note:Circulate 2 BU while troubleshooting ABI.;POH f/12526'to 12355',225k P/U pumps off,flowcheck well,static.continue to POH on elevators f/12355'to 8930' w/25k overpull,wash and backream f/8930'to 8891';Currently 49.17'below the line,12.82'right of the line.;Daily fluid losses=176 bbls total fluid losses=1185 bbls;-Hauled 575 bbls to G&I,total=13106 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 1450 bbls H2O F/L-Pad Lake,total=10425 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/7/2015 Continue to POH on elevators from 8891'to 5500'with no issues.Hole took calculated fill to the shoe.;Monitor well.Circulate btm up above shoe to clear any gas with 223 units.Hole unloaded at bottoms up with 50%increase in fine sands.Continue to circulate till clean.GPM 550,SPP 1750 psi.;Slug pipe and continue to TOH to 2600'standing back 5"DP.POOH from 2765'to BHA laying down 25 stds 5"DP.Std back HWDP&flex collars. Note:11 bbls over calc disp on trip out.;Down Load MWD Data.;Lay down BHA.Bit Graded:2-4-CT-G-X-I-WT-DTF.ILS stabilizer on bttm of ADR tool undercut approx 1/2".Clear rig floor.Stage New BHA components on floor.;MU BHA#7.New 8 1/2"PDC bit,xo,Geo pilot,DGR,PWD,smart stab,ADR,DM,TM collars,flt sub,upload MWD data,M/U 3 Flex collars,1 HWDP,jars,7 HWDP=460.43' Shallow test MWD tools.;M/U 1 single,park @ 519',Install FOSV,monitor well,cut and slip 66'Brig line.Re-set and test crown saver.;Monitor well,C/O saver sub, adjust top drive robotics pressure,service rig.UD FOSV.;TIH P/U 75 jts 5"DP previously UD f/519'to 2765',fill pipe.Continue to TIH with stds f/2765'to 5000'.;Daily fluid losses=58 bbls total fluid losses=1243 bbls;-Hauled 488 bbls to G&I,total=13594 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 0 bbls H2O F/L-Pad Lake,total=10425 bbls -Hauled 0 bbls of H2O FNern Lake,total=1073 bbls 9/8/2015 Continue to TIH on elevators from 5000'to 11,220'with no issues.Wash and ream f/11,220'to 11,300'.Continue TIH on elevators to 12,145'.Stacking wt.Attempt to pass through with no success.;Wash and Ream from 12,145'to 12,526'.Taking 15 to 20K WOB.Washed last stand down with no issues or fill on btm.;Drill 1/12,526'to 12,711'(185')AROP 33.6 FPH. WOB 10-25K,506 gpm-2240 psi,40-90RPM,12-15k ft/bs torq.P/U 205K,S/O 75K,ROT 135K. MW 9.3 ppg,vis 40.ECD 10.21 ppg.;Drill f/12,711'to 13,000'(289')AROP 48.1 FPH. WOB 10-25K,506 gpm-2420 psi,40-90 RPM,12-15k Mbs torq.P/U 205K,S/O 75K,ROT 135K. MW 9.3 ppg,vis 40.ECD 10.21 ppg.;Drill f/13,000'to 13,335'(335')AROP 55.8 FPH. WOB 10-25K,506 gpm-2420 psi,40-90 RPM,12-15k ft/Ibs torq.P/U 205K,S/O 75K,ROT 135K. MW 9.3 ppg,vis 40.ECD 10.61 ppg.;Currently 33.69 below the line,53.91 right of the line. Daily fluid losses=114 bbls Total fluid losses=1357 bbls;-Hauled 232 bbls to G&I,total=13826 bbls -Hauled 0 bbls to Pad 3,total=435 bbls -Hauled 450 bbls H2O F/L-Pad Lake,total=11325 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/9/2015 Drill f/13,335'to 13,445'(100')AROP 25 FPH. WOB 20-30K,550 gpm-2480psi,40-100 RPM,12-16k ft/Ibs torq.P/U 212K,S/O Rot 75K,ROT 130K. MW 9.2 ppg,vis 39.ECD 10.50 ppg;Drilling hard siderites/concretions in the OA-3 Target Zone;Drill f/13,445'to 13,690'(245')AROP 163.3 FPH.• WOB 10-20K,550 gpm-2490 psi,90-100 RPM,13-14k ft/lbs torq.P/U 212K,5/0 Rot 75K,ROT 130K. MW 9.2 ppg,vis 38.ECD 10.50 ppg.;Circulate hole clean surface to surface while Rot/Reciprocate pipe.GPM 550,SPP 2240,RPM 97,TD Tq 12-13K,P/U 145K, 5/0 125K.Max Gas @ 680u.;TOH from 13690'to 13510'P/U 225K.Hole not taking hole fill.TBIH to 13,660'.;Pump and circulate flagged sweep to surface.With 146u Max gas @ btm up.Sweep came back late w/10%washout calculated.GPM 554,SPP 2580,RPM 97,TD Tq 11.5-13K.;TOH on elevators(/13660'to last trip interval @ 12500'with no issues.Continue to TOH from 12500'to 11,425'.Encounter 50K over pull with no break over and unable to slack off.;Wash and ream from 11,425'up to 11,332.550 GPM,2040 psi.experience high Tq and stalls.Ream and back ream x 3.Pull clean.;Continue to TOH on elevators from 11,332' to 7430' with no issues.;Single out of hole f/7430'to inside the casing shoe laying down 5"Drill pipe, leaving 69 stands DP including HWDP in derrick(6500'). .;Circulate bottoms up @ the shoe to check for gas.145 units gas max at bottoms up. Monitor well,slug Pipe.;POOH laying down drill pipe. Calculated hole fill 109 bbls/Actual hole fill 131 bbls.;Work BHA.Stand back HWDP.Lay down remainder of BHA.;Daily fluid losses=165 bbls Total fluid losses=1522 bbls 33.99 Low,49.34 Right;Hauled 348 bbls to G&I,total=14,174 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 300 bbls H2O F/L-Pad Lake,total=11,175 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/10/2015 Continue to Lay down BHA.Grade Bit:1-2-CT-T-X-I-NO-TD.Clear BHA from Pipe Shed.;Drain Stack,Pull wear bushing.M/U Swizzel stick and wash out BOP. Blow down TDS and lay down swizzle stick.Set Test Plug.;Change out lower pipe rams f/5"to 2 7/8"Solid.Rig up to test BOP to 2 7/8"and 5'pipe size.;Test BOP to 250/3000 psi on 2 7/8"and 5"Pipe size with no failures. Test Gas alarms.Test witnessed by Lou Grimaldi.Rig down test equipment.;Load and Tally 5 1/2"Liner components.Load and tally 2 7/8"inner string,load and tally additional 5 1/2"Solid liner for shale zone/fault isolations.;RIH picking up 5 1/2"slotted liner assembly.;Daily fluid losses=43 bbls Total fluid losses=1565 bbls;-Hauled 191 bbls to G&I,total=14,365 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 65 bbls H2O F/L-Pad Lake,total=11,240 bbls -Hauled 0 bbls of H2O FNern Lake,total=1073 bbls • • Hilcorp Energy Company Composite Report Well Name: MP L-46 Field: North Slope County/State: ,Alaska I(LAT/LONG): evation(RKB): API#: Spud Date: Job Name: 1511124C MP L-46 Completion Contractor AFE#: 1511124C AFE$: $1,155,100 Activity Date Ops Summary 9/11/2015 Continue to TIH picking up 5 1/2"f/2850'to 7244'.,Rig up false bowl rotary.Rig 2 7/8"handling equipment.P/U 2 7/8"inner string. Established parameters at the shoe:P/U 118,S/O 92,Rt 104:10,20 and 30 RPM all=2400 ft/lbs.,Make up top assembly w/Cup Type Pack Off,Swivel,Ported Ball Seat Sub.Make up Liner Top Packer.Fill tie-back sleeve with Pal mix.,RIH with pipe out of derrick to 11,043'without issue.,Daily fluid losses=28 bbls Total fluid losses=1593 bbls,-Hauled 191 bbls to G&I,total=14,365 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 65 bbls H2O F/L-Pad Lake,total=11,240 bbls -Hauled 0 bbls of H2O FNem Lake,total=1073 bbls 9/12/2015 RIH with slotted liner assembly on 5'Drill pipe out of derrick f/11,043'to 13,190'on elevators with out issues.Setting down @ 13195'.MU top drive and Rotate liner to bottom with no pump from 13190'to TD @ 13690'.PU Single,record Up Wt 245,S/O 65K.Break Circulation @ 1 bpm w/250 psi.1.5 bpm w/300 psi,2 bpm w/370 psi,3 bpm 710 psi.Down on pump„Break off single,drop 1.75”OD Ball.Tag Bottom.PU to Up Wt+2'placing the shoe @ 13688'and Top of liner @ 6416'. Tie in Test Pump to Mud Manifold. Bring on MP and chase ball @ 3 bpm slowing rate to 1.5 bpm.Pump ball on seat,walk pressure up to 3000 psi.Slack off 50k and set hanger.Pressure up to 4000 psi to release HRD.Bleed off to zero.PU to free Wt @ 185K.,Set back Dn to 60k to set packer.Felt PKR Set.Pu to free Wt. Bring on rotary @ 15 RPM/4-5K Tq,set back down 60K and confirm set.P/U to up wt,S/O to new Dn wt @ 110K.PU to Free Wt.,Rig and Test Casing from Top Of PKR to surface.to 1500 psi for 15 min.Test GOOd.,POOH,UD and inspect running tools. Cross inner string over to DP.,Service rig and C/O grabber dies,CBU from 7200'to clear slug from annulus.,TIH to 6379'DP depth and 13630'Inner string depth.,Rig up to reverse circulate.Hold PJSM.,Reverse circulate bottoms up through choke manifold at 4 BPM/700 psi. Finish reverse circulating STS(without choke)at 4 BPM/730 psi.,Open annular preventer.Monitor well while holding PJSM.Displace well down drill string with 8.9 ppg 3%KCL at 6 BPM/2300 psi.Reciprocate pipe while pumping.Max gas 165 units.Calculated displacement=997 bbls.Actual displacement=1160 bbls.,Monitor well while mixing 100 bbls for TOH.,Daily fluid losses=44 bbls Total fluid losses=1637 bbls,-Hauled 191 bbls to G&I,total=14,365 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 65 bbls H2O F/L-Pad Lake,total=11,240 bbls -Hauled 1124 bbls of H2O FNem Lake,total=2197 bbls 9/13/2015 Monitor well while building 8.9 ppg 3%KCL volume.,TOH standing back 40 stands 5"Drill pipe.,Continue POOH laying down 5"DP and HWDP from 10,155'inner string depth to 7311',Slip and cut Drill line.Service Rig.Check brake linkage.,Change over to 2 7/8"handling equipment.TOH laying down 2 7/8"inner string from 7200'to surface.Well is static.,Pull wear bushing.Change upper pipe rams to 7 5/8"and bottom rams to 3 1/2".,Test rams/annular and floor valve as per sundry on chart at 250 L/3000 H. Lay down test joint.R/D test equipment.,Dummy run 7 5/8"tubing hanger.,Daily fluid losses=180 bbls Total fluid losses=1817 bbls,-Hauled 986 bbls to G&I,total=15,351 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 300 bbls H2O F/L-Pad Lake,total=11,540 bbls -Hauled 1124 bbls of H2O FNem Lake,total=2197 bbls 9/14/2015 Finish dummy run with 7 5/8"casing hanger.,Rig up to run 7 5/8"casing tie-back assembly.PU 7"Bullet Seal Assembly, 1)jt 7'csg,Tam Port collar, 1)jt 7"csg, XO 7"BTC pin x 7 5/8"511 Hyd. Run in hole picking up 7 5/8"29.7#L-80,511 Hyd casing from 94'to 2245'.Pu Wt 105K,Dn Wt 10OK,Continue run in hole picking up 7 5/8"29.7#L-80,511 Hyd casing from 2245'to 6416'. P/U 180K,S/O 132K.,Engage TOL at 6416'while circ.at 1 BPM/60 psi.Pressure increased.Down pump.Set down 10K on no-go. Space out.Make up pups,casing hanger and landing joint.,Circulate STS volume at 3 BPM/120 psi.,Land tie-back string and casing hanger.Install pack-off.Lay down landing joint and running tool.Test pack-off at 3000 psi/10 minutes.Good test.,M/U TAM combo tool.RIH picking up 3 1/2"drill pipe to 1375'.,Daily fluid losses=57 bbls Total fluid losses=1874 bbls,-Hauled 296 bbls to G&I,total=15,647 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 65 bbls H2O F/L-Pad Lake,total=11,605 bbls -Hauled 1124 bbls of H2O FNem Lake,total=2197 bbls 9/15/2015 RIH with TAM combo tool picking up 3 1/2"drill pipe 6268'Up Wt 120K Dn Wt 80K.,Park @ 6280'while W/O LRS to pump PKR Fluid and Freeze Protect.Rig down Geo pilot equipment to make room for ESP Spooler.Continue to load 2 7/8"completion in house.Prep for crane work.,Spot and rig up LRS to 9 5/8"x 7 5/8" annulus.PT lines.Continue to TIH and engage Tam Collar @ 6353' with 3K Dn.Pressure up drill pipe to 270 psi.Shift open with pressure dropping to 70 psi,pump 2 bbls down DP with returns out the by pass line to cutting tank indicating open.Slack off additional 15'and Park.,Close by pass to cutting tank.Bring on LRS and pump 65 bbls,follow with 41 bbls DSL Freeze Protect @ 2 bpm 550 psi.Close Tam collar,Pressure DP to 1000 psi indicating Tam closed. Utilize circulating time to perform Crane ops,loading in ESP Spooler and off loading Geo Pilot Skid and W.O.T power tongs.,LRS pressure test 9 5/8"x 7 5/8" Annulus to 1000 psi on chart for 30 minutes.Rig down LRS.Blow down top drive.Rig up to lay down 3 1/2"DP.,PJSM,TOH laying down 3 1/2"Drill pipe from 6300' to surface.,Clear rig floor and pipe shed.,Rig to run ESP:sheaves,spot equipment and stage components in pipe shed.,Pick up ESP components and dress same.,Daily fluid losses=36 bbls Total fluid losses=1910 bbls,-Hauled 296 bbls to G&I,total=15,647 bbls -Hauled 290 bbls to Pad 3,total=725 bbls -Hauled 65 bbls H2O F/L-Pad Lake,total=11,605 bbls -Hauled 1124 bbls of H2O FNem Lake,total=2197 bbls Hauled 250 bbls to B-50,total=250 bbls. • • 9/16/2015 Pick up and run in hole with 2 7/8"ESP Completion as follows:Centralizer,Sensor,Motor CL5,Lower Tandem Seal,Upper Tandem Seal,Gas Separator,Pump, Discharge Head,10'Pup Joint,8'Pup jt,X Nipple,8'Pup jt,4 jts tbg.7'Pup jt,GLM w/Dummy,8'Pup jt,123 jts tbg,9'Pup jt,GLM w/Oriface,Pup Jt,3 jts tbg,4' Pup jt,Tbg Hgr.,M/U Hanger and landing joint.,Make Tbg Hgr Penetrator Splice.,Land Hanger;RILD;laydown landing jnt.install BPV. Last Pick up and Slack off (70k up 62k down).,Install 2 3/8"pipe rams in the bop's,N/D BOP's. N/U Tree. Pull BPV and Install TWC.,R/U&Test Tree to 5000 psi.,Rig Down Test equipment &Rig up to freeze protect the IA. Bullheading 116 bbls down the backside and 14bbls inside the tbg.,Daily Fluid Loss:14 bbls Total Fluid Loss:1924 bbls,Hauled 0 bbls to G&I Total Hauled 15647 bbls Hauled 0 bbls to Pad 3 Total Hauled 725 bbls Hauled 275 bbls to B-50 Total Hauled 250 bbls Hauled 0 bbls H2O F/L-Pad Lake Total Hauled 11,605 bbls Hauled 0 bbls of H2O FNern Lake Total Hauled 2197 bbls 9/17/2015 Continue to Bullhead 116 bbls Dead Crude Freeze Protect down the backside and 14bbls inside the tbg.Rig down and release Little Red Services.,Dress tree, clean cellar area.Prep to move rig from L-46 to L-45.,Move rig from L-46 to L-45.Spot and set down Rig. RIG RELEASED FROM L-46 2 10:00 ON 9/17/15 • i Hilcorp Energy Company Milne Point M Pt L Pad MPL-46 5002923551 5002923551 Sperry Drilling Definitive Survey Report 18 September, 2015 HALLIBURTON Sperry Drilling .� .. . Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 Survey Calculation Method: Minimum Curvature Design: MPL-46 Database: Sperry EDM-NORTH US+CANADA Project Milne Point,ACT,MILNE POINT 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 MPL-46 Well Position +N/-S 0.00 usft Northing: 6,031,494.34 usft Latitude: 70°29'48.865 N +El-W 0.00 usft Easting: 545,147.71 usft Longitude: 149°37'50.916 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-46 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 8/15/2015 18.96 81.08 57,506 Design MPL-46 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,077.11 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 30.00 0.00 0.00 143.85 Survey Program Date 9/11/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 450.00 Survey#1 (MPL-46 PB1) SRG-MS Surface readout gyro multishot 08/12/2015 504.71 6,511.27 Survey#2(MPL-46 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 08/18/2015 6,607.41 12,077.11 Survey#3(MPL-46 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 08/31/2015 12,110.00 13,616.46 Survey#1(MPL-46) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 09/08/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17.50 0.00 0.00 6,031,494.34 545,147.71 0.00 0.00 UNDEFINED 90.00 0.22 84.10 90.00 42.50 0.01 0.11 6,031,494.35 545,147.82 0.37 0.06 SRG-MS(1) 150.00 0.22 39.91 150.00 102.50 0.11 0.30 6,031,494.45 545,148.01 0.28 0.09 SRG-MS(1) 250.00 0.30 65.65 250.00 202.50 0.37 0.66 6,031,494.71 545,148.37 0.14 0.10 SRG-MS(1) 350.00 1.75 89.31 349.98 302.48 0.49 2.43 6,031,494.85 545,150.14 1.48 1.04 SRG-MS(1) 450.00 3.82 102.33 449.86 402.36 -0.20 7.21 6,031,494.18 545,154.92 2.15 4.42 SRG-MS(1) 504.71 4.24 100.78 504.43 456.93 -0.97 10.98 6,031,493.44 545,158.69 0.79 7.26 MWD+IFR2+MS+sag(2) 600.04 6.51 100.89 599.34 551.84 -2.65 19.75 6,031,491.81 545,167.47 2.38 13.79 MWD+IFR2+MS+sag(2) 691.73 10.16 102.37 690.04 642.54 -5.36 32.76 6,031,489.18 545,180.50 3.99 23.65 MWD+IFR2+MS+sag(2) 786.30 10.47 101.90 783.08 735.58 -8.92 49.31 6,031,485.72 545,197.07 0.34 36.29 MWD+IFR2+MS+sag(2) 881.38 11.48 101.33 876.42 828.92 -12.56 67.04 6,031,482.19 545,214.82 1.07 49.69 MWD+IFR2+MS+sag(2) 9/18/2015 12:40:44PM Page 2 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 Survey Calculation Method: Minimum Curvature Design: MPL-46 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) ((t) (ft) (°/100') (ft) Survey Tool Name 974.45 11.13 100.02 967.69 920.19 -15.94 84.97 6,031,478.91 545,232.77 0.47 63.00 MWD+IFR2+MS+sag(2) 1,071.95 11.78 101.07 1,063.25 1,015.75 -19.49 104.00 6,031,475.48 545,251.82 0.70 77.09 MWD+IFR2+MS+sag(2) 1,163.70 10.24 114.66 1,153.32 1,105.82 -24.69 120.61 6,031,470.38 545,268.46 3.28 91.09 MWD+IFR2+MS+sag(2) 1,259.78 8.13 131.86 1,248.18 1,200.68 -32.79 133.44 6,031,462.36 545,281.33 3.58 105.19 MWD+IFR2+MS+sag(2) 1,353.90 7.79 150.83 1,341.41 1,293.91 -42.81 141.50 6,031,452.40 545,289.46 2.80 118.04 MWD+IFR2+MS+sag(2) 1,448.41 7.80 164.95 1,435.05 1,387.55 -54.59 146.29 6,031,440.64 545,294.32 2.02 130.38 MWD+IFR2+MS+sag(2) 1,542.33 7.47 169.67 1,528.14 1,480.64 -66.75 149.04 6,031,428.50 545,297.14 0.75 141.82 MWD+IFR2+MS+sag(2) 1,637.24 9.42 189.65 1,622.04 1,574.54 -80.49 148.84 6,031,414.77 545,297.03 3.68 152.79 MWD+IFR2+MS+sag(2) 1,731.20 11.90 209.89 1,714.40 1,666.90 -96.47 142.73 6,031,398.75 545,291.00 4.74 162.09 MWD+IFR2+MS+sag(2) 1,826.63 14.12 215.43 1,807.38 1,759.88 -114.49 131.07 6,031,380.66 545,279.46 2.67 169.77 MWD+IFR2+MS+sag(2) 1,920.84 16.07 218.33 1,898.34 1,850.84 -134.08 116.32 6,031,360.98 545,264.83 2.22 176.89 MWD+IFR2+MS+sag(2) 2,014.59 20.39 219.36 1,987.36 1,939.86 -156.90 97.91 6,031,338.05 545,246.56 4.62 184.45 MWD+IFR2+MS+sag(2) 2,108.68 21.68 219.73 2,075.18 2,027.68 -182.94 76.40 6,031,311.88 545,225.22 1.38 192.79 MWD+IFR2+MS+sag(2) 2,202.33 26.22 221.63 2,160.74 2,113.24 -211.72 51.59 6,031,282.95 545,200.58 4.92 201.40 MWD+IFR2+MS+sag(2) 2,296.00 28.04 225.07 2,244.11 2,196.61 -242.74 22.25 6,031,251.76 545,171.43 2.56 209.14 MWD+IFR2+MS+sag(2) 2,391.60 32.96 228.44 2,326.46 2,278.96 -275.89 -13.14 6,031,218.40 545,136.25 5.45 215.02 MWD+IFR2+MS+sag(2) 2,485.47 34.42 230.37 2,404.57 2,357.07 -309.75 -52.68 6,031,184.30 545,096.92 1.93 219.04 MWD+IFR2+MS+sag(2) 2,579.41 38.37 231.03 2,480.17 2,432.67 -345.04 -95.82 6,031,148.76 545,054.00 4.23 222.09 MWD+IFR2+MS+sag(2) 2,674.42 39.75 232.18 2,553.94 2,506.44 -382.21 -142.74 6,031,111.30 545,007.31 1.64 224.42 MWD+IFR2+MS+sag(2) 2,768.57 42.12 233.10 2,625.06 2,577.56 -419.63 -191.77 6,031,073.59 544,958.51 2.60 225.72 MWD+IFR2+MS+sag(2) 2,862.53 44.83 233.69 2,693.24 2,645.74 -458.17 -243.67 6,031,034.74 544,906.85 2.92 226.22 MWD+IFR2+MS+sag(2) 2,956.90 47.76 231.90 2,758.44 2,710.94 -499.44 -297.98 6,030,993.15 544,852.80 3.39 227.50 MWD+IFR2+MS+sag(2) 3,051.36 49.87 232.89 2,820.64 2,773.14 -542.80 -354.30 6,030,949.45 544,796.75 2.37 229.30 MWD+IFR2+MS+sag(2) 3,145.34 52.56 232.92 2,879.50 2,832.00 -586.98 -412.73 6,030,904.92 544,738.59 2.86 230.51 MWD+IFR2+MS+sag(2) 3,239.99 56.14 235.04 2,934.67 2,887.17 -632.18 -474.94 6,030,859.35 544,676.66 4.20 230.30 MWD+IFR2+MS+sag(2) 3,334.30 58.51 235.29 2,985.58 2,938.08 -677.52 -540.10 6,030,813.62 544,611.79 2.52 228.47 MWD+IFR2+MS+sag(2) 3,428.97 59.88 235.20 3,034.06 2,986.56 -723.87 -806.90 6,030,766.87 544,545.28 1.45 226.50 MWD+IFR2+MS+sag(2) 3,523.63 65.26 233.25 3,077.65 3,030.15 -772.99 -675.02 6,030,717.34 544,477.47 5.97 225.98 MWD+IFR2+MS+sag(2) 3,617.82 65.87 232.45 3,116.61 3,069.11 -824.78 -743.36 6,030,665.14 544,409.44 1.01 227.48 MWD+IFR2+MS+sag(2) 3,712.88 64.80 232.68 3,156.28 3,108.78 -877.29 -811.96 6,030,612.22 544,341.17 1.15 229.42 MWD+IFR2+MS+sag(2) 3,806.68 64.86 232.33 3,196.18 3,148.68 -928.97 -879.31 6,030,560.14 544,274.14 0.34 231.41 MWD+IFR2+MS+sag(2) 3,901.26 64.94 231.80 3,236.30 3,188.80 -981.62 -946.86 6,030,507.08 544,206.92 0.51 234.08 M1ND+IFR2+MS+sag(2) 3,995.68 64.53 232.07 3,276.60 3,229.10 -1,034.27 -1,014.09 6,030,454.03 544,140.02 0.51 236.93 MWD+IFR2+MS+sag(2) 4,090.44 64.40 231.23 3,317.45 3,269.95 -1,087.32 -1,081.15 6,030,400.58 544,073.29 0.81 240.21 MWD+IFR2+MS+sag(2) 4,184.25 64.17 231.16 3,358.15 3,310.65 -1,140.28 -1,147.01 6,030,347.22 544,007.76 0.25 244.13 MWD+IFR2+MS+sag(2) 4,278.15 63.94 231.59 3,399,23 3,351.73 -1,192.99 -1,212.98 6,030,294.12 543,942.12 0.48 247.77 MWD+IFR2+MS+sag(2) 4,372.60 63.46 226.45 3,441.10 3,393.60 -1,248.49 -1,276.87 6,030,238.24 543,878.57 4.90 254.89 MWD+IFR2+MS+sag(2) 4,466.21 62.39 222.41 3,483.72 3,436.22 -1,307.98 -1,335.22 6,030,178.40 543,820.59 4.01 268.52 MWD+IFR2+MS+sag(2) 4,561.79 61.35 216.85 3,528.81 3,481.31 -1,372.85 -1,388.96 6,030,113.21 543,767.25 5.24 289.19 MWD+IFR2+MS+sag(2) 4,655.70 61.76 210.36 3,573.58 3,526.08 -1,441.57 -1,434.62 6,030,044.22 543,722.01 6.09 317.75 MWD+IFR2+MS+sag(2) 9/18/2015 12:40:44PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 m 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 Survey Calculation Method: Minimum Curvature Design: MPL-46 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc AzI ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 4,750.48 62.10 201.97 3,618.24 3,570.74 -1,516.54 -1,471.44 6,029,969.04 543,685.65 7.82 356.57 MWD+IFR2+MS+sag(2) 4,844.84 62.35 196.67 3,662.24 3,614.74 -1,595.29 -1,499.04 6,029,890.13 543,658.53 4.98 403.87 MWD+IFR2+MS+sag(2) 4,939.43 62.52 191.26 3,706.04 3,658.54 -1,676.62 -1,519.27 6,029,808.69 543,638.80 5.07 457.61 MWD+IFR2+MS+sag(2) 5,033.56 62.37 187.71 3,749.59 3,702.09 -1,758.91 -1,533.02 6,029,726.32 543,625.55 3.35 515.95 MWD+IFR2+MS+sag(2) 5,128.41 62.96 182.26 3,793.17 3,745.67 -1,842.81 -1,540.32 6,029,642.39 543,618.76 5.14 579.38 MWD+IFR2+MS+sag(2) 5,221.71 64.31 178.32 3,834.62 3,787.12 -1,926.38 -1,540.73 6,029,558.83 543,618.86 4.05 646.62 MWD+IFR2+MS+sag(2) 5,316.81 65.67 173.62 3,874.84 3,827.34 -2,012.31 -1,534.66 6,029,472.94 543,625.45 4.70 719.60 MWD+IFR2+MS+sag(2) 5,411.68 68.23 167.67 3,912.01 3,864.51 -2,098.38 -1,520.43 6,029,386.97 543,640.20 6.37 797.49 MWD+IFR2+MS+sag(2) 5,505.83 68.92 160.86 3,946.44 3,898.94 -2,182.68 -1,496.67 6,029,302.83 543,664.47 6.77 879.57 MWD+IFR2+MS+sag(2) 5,600.09 70.61 154.33 3,979.07 3,931.57 -2,264.37 -1,462.96 6,029,221.34 543,698.67 6.74 965.42 MWD+IFR2+MS+sag(2) 5,694.83 70.76 149.34 4,010.42 3,962.92 -2,343.16 -1,420.77 6,029,142.82 543,741.33 4.97 1,053.93 MWD+IFR2+MS+sag(2) 5,761.47 72.15 147.34 4,031.62 3,984.12 -2,396.93 -1,387.61 6,029,089.26 543,774.82 3.53 1,116.91 MWD+IFR2+MS+sag(2) 5,850.59 71.73 146.87 4,059.25 4,011.75 -2,468.08 -1,341.60 6,029,018.40 543,821.26 0.69 1,201.50 MWD+IFR2+MS+sag(2) 5,944.83 74.69 140.59 4,086.49 4,038.99 -2,540.75 -1,288.23 6,028,946.07 543,875.08 7.11 1,291.66 MWD+IFR2+MS+sag(2) 6,039.01 77.02 136.74 4,109.51 4,062.01 -2,609.29 -1,227.92 6,028,877.90 543,935.78 4.67 1,382.59 MWD+IFR2+MS+sag(2) 6,133.40 82.24 133.82 4,126.50 4,079.00 -2,675.22 -1,162.60 6,028,812.37 544,001.49 6.31 1,474.35 MWD+IFR2+MS+sag(2) 6,227.74 83.78 129.26 4,137.99 4,090.49 -2,737.29 -1,092.53 6,028,750.73 544,071.93 5.07 1,565.81 MWD+IFR2+MS+sag(2) 6,322.31 84.75 124.40 4,147.44 4,099.94 -2,793.67 -1,017.23 6,028,694.81 544,147.56 5.22 1,655.76 MWD+IFR2+MS+sag(2) 6,416.80 84.01 124.35 4,156.70 4,109.20 -2,846.77 -939.62 6,028,642.20 544,225.49 0.78 1,744.41 MWD+IFR2+MS+sag(2) 6,511.27 83.70 123.60 4,166.81 4,119.31 -2,899.26 -861.73 6,028,590.19 544,303.69 0.85 1,832.74 MWD+IFR2+MS+sag(2) 6,607.41 88.15 122.31 4,173.64 4,126.14 -2,951.41 -781.28 6,028,538.53 544,384.44 4.82 1,922.31 MWD+IFR2+MS+sag(3) 6,701.93 87.90 119.46 4,176.90 4,129.40 -2,999.89 -700.22 6,028,490.55 544,465.79 3.03 2,009.28 MWD+IFR2+MS+sag(3) 6,796.69 89.20 119.85 4,179.30 4,131.80 -3,046.76 -617.90 6,028,444.18 544,548.38 1.43 2,095.68 MWD+IFR2+MS+sag(3) 6,890.47 90.55 121.22 4,179.50 4,132.00 -3,094.40 -537.13 6,028,397.03 544,629.43 2.05 2,181.80 MWD+IFR2+MS+sag(3) 6,985.52 91.05 123.44 4,178.17 4,130.67 -3,145.23 -456.83 6,028,346.70 544,710.04 2.39 2,270.21 MWD+IFR2+MS+sag(3) 7,079.81 90.43 125.60 4,176.96 4,129.46 -3,198.65 -379.15 6,028,293.76 544,788.03 2.38 2,359.17 MWD+IFR2+MS+sag(3) 7,174.31 89.81 125.26 4,176.76 4,129.26 -3,253.44 -302.15 6,028,239.45 544,865.35 0.75 2,448.83 MWD+IFR2+MS+sag(3) 7,269.12 89.20 125.43 4,177.58 4,130.08 -3,308.28 -224.82 6,028,185.08 544,943.01 0.67 2,538.73 MWD+IFR2+MS+sag(3) 7,363.38 89.20 126.13 4,178.89 4,131.39 -3,363.39 -148.36 6,028,130.44 545,019.80 0.74 2,628.33 MWD+IFR2+MS+sag(3) 7,458.01 89.50 124.89 4,179.97 4,132.47 -3,418.35 -71.34 6,028,075.96 545,097.14 1.35 2,718.15 MWD+IFR2+MS+sag(3) 7,552.19 89.07 124.51 4,181.14 4,133.64 -3,471.96 6.09 6,028,022.82 545,174.88 0.61 2,807.11 MWD+IFR2+MS+sag(3) 7,646.35 89.07 125.14 4,182.67 4,135.17 -3,525.72 83.37 6,027,969.53 545,252.49 0.67 2,696.12 MWD+IFR2+MS+sag(3) 7,739.95 88.95 124.56 4,184.29 4,136.79 -3,579.20 160.17 6,027,916.53 545,329.60 0.63 2,984.60 MWD+IFR2+MS+sag(3) 7,835.20 89.26 122.84 4,185.78 4,138.28 -3,632.04 239.41 6,027,864.18 545,409.15 1.83 3,074.01 MWD+IFR2+MS+sag(3) 7,928.70 89.13 121.06 4,187.09 4,139.59 -3,681.51 318.73 6,027,815.19 545,488.76 1.91 3,160.75 MWD+IFR2+MS+sag(3) 8,024.43 90.12 123.79 4,187.72 4,140.22 -3,732.83 399.52 6,027,764.37 545,569.86 3.03 3,249.85 MWD+IFR2+MS+sag(3) 8,117.66 89.38 125.26 4,188.12 4,140.62 -3,785.67 476.33 6,027,712.00 545,646.98 1.77 3,337.83 MWD+IFR2+MS+sag(3) 8,213.21 87.96 124.72 4,190.34 4,142.84 -3,840.45 554.59 6,027,657.71 545,725.56 1.59 3,428.22 MWD+IFR2+MS+sag(3) 8,306.54 88.15 123.55 4,193.51 4,146.01 -3,892.79 631.79 6,027,605.84 545,803.07 1.27 3,516.03 MWD+IFR2+MS+sag(3) 8,400.37 89.94 123.59 4,195.07 4,147.57 -3,944.66 709.96 6,027,554.45 545,881.54 1.91 3,604.02 MWD+IFR2+MS+sag(3) 9/18/2015 12:40:44PM Page 4 COMPASS 5000.1 Build 73 S I Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 Survey Calculation Method: Minimum Curvature Design: MPL-46 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (tisk) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,493.90 89.26 123.71 4,195.72 4,148.22 -3,996.49 787.81 6,027,503.10 545,959.71 0.74 3,691.80 MWD+IFR2+MS+sag(3) 8,589.77 88.83 124.73 4,197.32 4,149.82 -4,050.39 867.08 6,027,449.68 546,039.28 1.15 3,782.08 MWD+IFR2+MS+sag(3) 8,685.03 91.42 125.06 4,197.11 4,149.61 -4,104.88 945.20 6,027,395.67 546,117.73 2.74 3,872.17 MWD+IFR2+MS+sag(3) 8,779.35 94.89 125.37 4,191.92 4,144.42 -4,159.18 1,022.13 6,027,341.85 546,194.98 3.69 3,961.39 MWD+IFR2+MS+sag(3) 8,873.38 94.88 124.68 4,183.92 4,136.42 -4,212.95 1,098.85 6,027,288.55 546,272.02 0.73 4,050.07 MWD+IFR2+MS+sag(3) 8,968.22 94.88 124.98 4,175.85 4,128.35 -4,266.92 1,176.42 6,027,235.06 546,349.91 0.32 4,139.41 MWD+IFR2+MS+sag(3) 9,061.91 91.61 124.29 4,170.55 4,123.05 -4,320.08 1,253.37 6,027,182.38 546,427.17 3.57 4,227.72 MWD+IFR2+MS+sag(3) 9,156.07 90.86 126.06 4,168.52 4,121.02 4,374.31 1,330.32 6,027,128.62 546,504.44 2.04 4,316.90 MWD+IFR2+MS+sag(3) 9,250.42 88.76 125.72 4,168.83 4,121.33 -4,429.61 1,406.75 6,027,073.78 546,581.20 2.25 4,406.65 MWD+IFR2+MS+sag(3) 9,345.17 89.88 125.14 4,169.95 4,122.46 -4,484.54 1,483.95 6,027,019.34 546,658.72 1.33 4,496.54 MWD+IFR2+MS+sag(3) 9,439.44 90.99 126.62 4,169.24 4,121.74 -4,539.78 1,560.32 6,026,964.56 546,735.42 1.96 4,586.20 MWD+IFR2+MS+sag(3) 9,533.82 91.30 125.46 4,167.35 4,119.85 -4,595.30 1,636.62 6,026,909.51 546,812.05 1.27 4,676.04 MWD+IFR2+MS+sag(3) 9,627.84 92.59 124.59 4,164.16 4,116.66 -4,649.23 1,713.57 6,026,856.06 546,889.32 1.65 4,764.97 MWD+IFR2+MS+sag(3) 9,722.55 92.66 123.69 4,159.82 4,112.32 -4,702.33 1,791.88 6,026,803.44 546,967.94 0.95 4,854.04 MWD+IFR2+MS+sag(3) 9,816.88 90.00 123.53 4,157.63 4,110.13 -4,754.52 1,870.41 6,026,751.73 547,046.78 2.82 4,942.51 MWD+IFR2+MS+sag(3) 9,911.26 84.87 123.15 4,161.86 4,114.36 -4,806.32 1,949.15 6,026,700.41 547,125.82 5.45 5,030.79 MWD+IFR2+MS+sag(3) 10,005.66 84.81 122.93 4,170.35 4,122.85 -4,857.58 2,027.96 6,026,649.64 547,204.94 0.24 5,118.68 MWD+IFR2+MS+sag(3) 10,100.37 83.26 123.15 4,180.19 4,132.89 -4,908.94 2,106.92 6,026,598.76 547,284.20 1.65 5,206.73 MWD+IFR2+MS+sag(3) 10,194.89 83.32 123.48 4,191.23 4,143.73 -4,960.50 2,185.37 6,026,547.69 547,362.95 0.35 5,294.63 MWD+IFR2+MS+sag(3) 10,289.13 84.68 125.24 4,201.08 4,153.58 -5,013.40 2,262.73 6,026,495.27 547,440.63 2.35 5,382.98 MWD+IFR2+MS+sag(3) 10,383.33 84.86 125.33 4,209.67 4,162.17 -5,067.58 2,339.31 6,026,441.55 547,517.52 0.21 5,471.91 MWD+IFR2+MS+sag(3) 10,478.02 87.16 126.60 4,216.26 4,168.76 -5,123.05 2,415.76 6,026,386.55 547,594.30 2.77 5,561.80 MWD+IFR2+MS+sag(3) 10,569.19 87.78 125.87 4,220.28 4,172.78 -5,176.89 2,489.22 6,026,333.17 547,668.08 1.05 5,648.61 MWD+IFR2+MS+sag(3) 10,663.75 88.45 124.85 4,223.39 4,175.89 -5,231.58 2,566.29 6,026,278.95 547,745.48 1.29 5,738.24 MWD+IFR2+MS+sag(3) 10,759.28 90.12 123.05 4,224.59 4,177.09 -5,284.93 2,645.53 6,026,226.09 547,825.03 2.57 5,828.05 MWD+IFR2+MS+sag(3) 10,855.66 90.80 121.76 4,223.81 4,176.31 -5,336.57 2,726.89 6,026,174.95 547,906.70 1.51 5,917.75 MWD+IFR2+MS+sag(3) 10,950.04 90.12 120.54 4,223.06 4,175.56 -5,385.39 2,807.66 6,026,126.63 547,987.75 1.48 6,004.81 MWD+IFR2+MS+sag(3) 11,044.50 90.93 120.78 4,222.19 4,174.69 -5,433.56 2,888.91 6,026,078.96 548,069.29 0.89 6,091.64 MWD+IFR2+MS+sag(3) 11,136.92 87.59 121.65 4,223.38 4,175.88 -5,481.44 2,967.93 6,026,031.56 548,148.59 3.73 6,176.92 MWD+IFR2+MS+sag(3) 11,232.36 90.62 123.89 4,224.87 4,177.37 -5,533.09 3,048.16 6,025,980.41 548,229.12 3.95 6,265.95 MWD+IFR2+MS+sag(3) 11,324.95 92.59 123.61 4,222.28 4,174.78 -5,584.50 3,125.11 6,025,929.46 548,306.38 2.15 6,352.86 MWD+IFR2+MS+sag(3) 11,421.26 90.74 121.93 4,219.48 4,171.98 -5,636.61 3,206.05 6,025,877.86 548,387.62 2.59 6,442.68 MWD+IFR2+MS+sag(3) 11,515.99 90.49 119.69 4,218.47 4,170.97 -5,685.12 3,287.40 6,025,829.84 548,469.26 2.38 6,529.84 MWD+IFR2+MS+sag(3) 11,610.29 90.25 117.93 4,217.86 4,170.36 -5,730.56 3,370.03 6,025,784.91 548,552.15 1.88 6,615.27 MWD+IFR2+MS+sag(3) 11,704.57 93.28 122.22 4,214.95 4,167.45 -5,777.77 3,451.55 6,025,738.21 548,633.95 5.57 6,701.48 MWD+IFR2+MS+sag(3) 11,799.11 93.83 124.39 4,209.09 4,161.59 -5,829.58 3,530.40 6,025,686.88 548,713.11 2.36 6,789.83 MWD+IFR2+MS+sag(3) 11,887.88 92.34 124.90 4,204.31 4,156.81 -5,879.97 3,603.33 6,025,636.94 548,786.33 1.77 6,873.53 MWD+IFR2+MS+sag(3) 11,982.72 90.37 125.95 4,202.07 4,154.57 -5,934.92 3,680.58 6,025,582.46 548,863.91 2.35 6,963.48 MWD+IFR2+MS+sag(3) 12,077.11 88.45 128.40 4,203.04 4,155.54 -5,991.95 3,755.78 6,025,525.90 548,939.44 3.30 7,053.89 MWD+IFR2+MS+sag(3) 12,110.00 88.45 128.40 4,203.93 4,156.43 -6,012.37 3,781.54 6,025,505.64 548,965.33 0.00 7,085.58 MWD+IFR2+MS+sag(4) 9/18/2015 12:40:44PM Page 5 COMPASS 5000.1 Build 73 S • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 Survey Calculation Method: Minimum Curvature Design: MPL-46 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-S +Ef-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°HOOP) (ft) Survey Tool Name 12,170.04 86.54 129.78 4,206.55 4,159.05 -6,050.19 3,828.10 6,025,468.11 549,012.11 3.92 7,143.58 MWD+1FR2+MS+sag(4) 12,264.73 87.10 131.52 4,211.81 4,164.31 -6,111.77 3,899.83 6,025,406.96 549,084.20 1.93 7,235.62 MWD+IFR2+MS+sag(4) 12,358.98 88.95 132.53 4,215.06 4,167.56 -6,174.83 3,969.79 6,025,344.34 549,154.54 2.24 7,327.81 MWD+IFR2+MS+sag(4) 12,454.90 91.30 133.62 4,214.85 4,167.35 -6,240.33 4,039.85 6,025,279.27 549,224.99 2.70 7,422.03 MWD+IFR2+MS+sag(4) 12,547.90 93.64 131.34 4,210.84 4,163.34 -6,303.07 4,108.37 6,025,216.95 549,293.88 3.51 7,513.11 MWD+IFR2+MS+sag(4) 12,643.91 95.82 127.83 4,202.92 4,155.42 -6,364.03 4,182.09 6,025,156.44 549,367.96 4.29 7,605.82 MWD+IFR2+MS+sag(4) 12,737.41 93.71 124.67 4,195.15 4,147.65 -6,419.12 4,257.22 6,025,101.82 549,443.42 4.05 7,694.62 MWD+IFR2+MS+sag(4) 12,831.02 91.54 124.90 4,190.86 4,143.36 -6,472.46 4,334.02 6,025,048.95 549,520.53 2.33 7,783.00 MWD+IFR2+MS+sag(4) 12,927.64 91.54 126.35 4,188.27 4,140.77 -6,528.72 4,412.52 6,024,993.18 549,599.37 1.50 7,874.73 MWD+IFR2+MS+sag(4) 13,020.33 90.56 126.58 4,186.57 4,139.07 -6,583.80 4,487.05 6,024,938.56 549,674.23 1.09 7,963.17 MWD+IFR2+MS+sag(4) 13,115.68 90.99 127.72 4,185.28 4,137.78 -6,641.37 4,563.04 6,024,881.45 549,750.56 1.28 8,054.49 MWD+IFR2+MS+sag(4) 13,209.27 89.51 126.83 4,184.87 4,137.37 -6,698.05 4,637.51 6,024,825.23 549,825.36 1.85 8,144.19 MWD+IFR2+MS+sag(4) 13,304.24 90.00 125.78 4,185.28 4,137.78 -6,754.28 4,714.05 6,024,769.47 549,902.23 1.22 8,234.74 MWD+IFR2+MS+sag(4) 13,398.60 91.85 126.07 4,183.75 4,136.25 -6,809.64 4,790.44 6,024,714.59 549,978.95 1.98 8,324.50 MWD+IFR2+MS+sag(4) 13,493.06 91.23 122.64 4,181.21 4,133.71 -6,862.91 4,868.39 6,024,661.79 550,057.21 3.69 8,413.50 MWD+IFR2+MS+sag(4) 13,587.73 90.62 120.68 4,179.69 4,132.19 -6,912.59 4,948.95 6,024,612.61 550,138.07 2.17 8,501.14 MWD+IFR2+MS+sag(4) 13,616.46 91.17 119.80 4,179.24 4,131.74 -6,927.06 4,973.77 6,024,598.29 550,162.97 3.61 8,527.46 MWD+IFR2+MS+sag(4) 13,690.00 91.17 119.80 4,177.74 4,130.24 -6,963.60 5,037.57 6,024,562.14 550,226.99 0.00 8,594.61 PROJECTED to TD brian.wheeler@hallibur.....,w.aa... „.<- w....... Checked By: ton.com .,300,.0 ,0„�1.,,Approved By: cary.taylor@ha��burton.com zw�� Date: 9/18/2015 12:40:44PM Page 6 COMPASS 5000.1 Build 73 • Hilcorp Energy Company Milne Point M Pt L Pad MPL-46 PB1 500292355170 500292355170 Sperry Drilling Definitive Survey Report 18 September, 2015 HALLIBURTON • • Sperry Driliing • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 PB1 Survey Calculation Method: Minimum Curvature Design: MPL-46 PBI Database: Sperry EDM-NORTH US+CANADA Project Milne Point,ACT,MILNE POINT 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 MPL-46 Well Position +NI-S 0.00 usft Northing: 6,031494.34 usft Latitude: 70°29'48.865 N +E/-W 0.00 usft Easting: 545,147.71 usft Longitude: 149°37'50.916 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.50 usft Wellbore MPL-46 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/15/2015 18.96 81.08 57,506 Design MPL-46 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 30.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 143.85 Survey Program Date 9/11/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 90.00 450.00 Survey#1(MPL-46 PB1) SRG-MS Surface readout gyro multishot 08/12/2015 504.71 6,511.27 Survey#2(MPL-46 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 08/18/2015 6,607.41 12,077.11 Survey#3(MPL-46 PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 08/31/2015 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 30.00 0.00 0.00 30.00 -17.50 0.00 0.00 6,031,494.34 545,147.71 0.00 0.00 UNDEFINED 90.00 0.22 84.10 90.00 42.50 0.01 0.11 6,031,494.35 545,147.82 0.37 0.06 SRG-MS(1) 150.00 0.22 39.91 150.00 102.50 0.11 0.30 6,031,494.45 545,148.01 0.28 0.09 SRG-MS(1) 250.00 0.30 65.65 250.00 202.50 0.37 0.66 6,031,494.71 545,148.37 0.14 0.10 SRG-MS(1) 350.00 1.75 89.31 349.98 302.48 0.49 2.43 6,031,494.85 545,150.14 1.48 1.03 SRG-MS(1) 450.00 3.82 102.33 449.86 402.36 -0.20 7.21 6,031,494.18 545,154.92 2.15 4.42 SRG-MS(1) 504.71 4.24 100.78 504.43 456.93 -0.97 10.98 6,031,493.44 545,158.69 0.79 7.26 MWD+IFR2+MS+sag(2) 600.04 6.51 100.89 599.34 551.84 -2.65 19.75 6,031,491.81 545,167.47 2.38 13.79 MWD+IFR2+MS+sag(2) 691.73 10.16 102.37 690.04 642.54 -5.36 32.76 6,031,489.18 545,180.50 3.99 23.65 MWD+IFR2+MS+sag(2) 786.30 10.47 101.90 783.08 735.58 -8.92 49.31 6,031,485.72 545,197.07 0.34 36.29 MWD+IFR2+MS+sag(2) 881.38 11.48 101.33 876.42 828.92 -12.56 67.04 6,031,482.19 545,214.82 1.07 49.69 MWD+IFR2+MS+sag(2) 974.45 11.13 100.02 967.69 920.19 -15.94 84.97 6,031,478.91 545,232.77 0.47 63.00 MWD+IFR2+MS+sag(2) 9/18/2015 12:39:OOPM Page 2 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 PB1 Survey Calculation Method: Minimum Curvature Design: MPL-46 PB1 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) (0/100') (ft) Survey Tool Name 1,071.95 11.78 101.07 1,063.25 1,015.75 -19.49 104.00 6,031,475.48 545,251.82 0.70 77.09 MWD+IFR2+MS+sag(2) 1,163.70 10.24 114.66 1,153.32 1,105.82 -24.69 120.61 6,031,470.38 545,268.46 3.28 91.09 MWD+IFR2+MS+sag(2) 1,259.78 8.13 131.86 1,248.18 1,200.68 -32.79 133.44 6,031,462.36 545,281.33 3.58 105.19 MWD+IFR2+MS+sag(2) 1,353.90 7.79 150.83 1,341.41 1,293.91 -42.81 141.50 6,031,452.40 545,289.46 2.80 118.03 MWD+IFR2+MS+sag(2) 1,448.41 7.80 164.95 1,435.05 1,387.55 -54.59 146.29 6,031,440.64 545,294.32 2.02 130.38 MWD+IFR2+MS+sag(2) 1,542.33 7.47 169.67 1,528.14 1,480.64 -66.75 149.04 6,031,428.50 545,297.14 0.75 141.82 MWD+IFR2+MS+sag(2) 1,637.24 9.42 189.65 1,622.04 1,574.54 -80.49 148.84 6,031,414.77 545,297.03 3.68 152.79 MWD+IFR2+MS+sag(2) 1,731.20 11.90 209.89 1,714.40 1,666.90 -96.47 142.73 6,031,398.75 545,291.00 4.74 162.09 MWD+IFR2+MS+sag(2) 1,826.63 14.12 215.43 1,807.38 1,759.88 -114.49 131.07 6,031,380.66 545,279.46 2.67 169.77 MWD+IFR2+MS+sag(2) 1,920.84 16.07 218.33 1,898.34 1,850.84 -134.08 116.32 6,031,360.98 545,264.83 2.22 176.89 MWD+IFR2+MS+sag(2) 2,014.59 20.39 219.36 1,987.36 1,939.86 -156.90 97.91 6,031,338.05 545,246.56 4.62 184.45 MWD+IFR2+MS+sag(2) 2,108.68 21.68 219.73 2,075.18 2,027.68 -182.94 76.40 6,031,311.88 545,225.22 1.38 192.79 MWD+IFR2+MS+sag(2) 2,202.33 26.22 221.63 2,160.74 2,113.24 -211.72 51.59 6,031,282.95 545,200.58 4.92 201.40 MWD+IFR2+MS+sag(2) 2,296.00 28.04 225.07 2,244.11 2,196.61 -242.74 22.25 6,031,251.76 545,171.43 2.56 209.14 MWD+IFR2+MS+sag(2) 2,391.60 32.96 228.44 2,326.46 2,278.96 -275.89 -13.14 6,031,218.40 545,136.25 5.45 215.03 MWD+IFR2+MS+sag(2) 2,485.47 34.42 230.37 2,404.57 2,357.07 -309.75 -52.68 6,031,184.30 545,096.92 1.93 219.05 MWD+IFR2+MS+sag(2) 2,579.41 38.37 231.03 2,480.17 2,432.67 -345.04 -95.82 6,031,148.76 545,054.00 4.23 222.10 MWD+IFR2+MS+sag(2) 2,674.42 39.75 232.18 2,553.94 2,506.44 -382.21 -142.74 6,031,111.30 545,007.31 1.64 224.44 MWD+IFR2+MS+sag(2) 2,768.57 42.12 233.10 2,625.06 2,577.56 -419.63 -191.77 6,031,073.59 544,958.51 2.60 225.73 MWD+IFR2+MS+sag(2) 2,862.53 44.83 233.69 2,693.24 2,645.74 -458.17 -243.67 6,031,034.74 544,906.85 2.92 226.24 MWD+IFR2+MS+sag(2) 2,956.90 47.76 231.90 2,758.44 2,710.94 -499.44 -297.98 6,030,993.15 544,852.80 3.39 227.53 MWD+IFR2+MS+sag(2) 3,051.36 49.87 232.89 2,820.64 2,773.14 -542.80 -354.30 6,030,949.45 544,796.75 2.37 229.33 MWD+IFR2+MS+sag(2) 3,145.34 52.56 232.92 2,879.50 2,832.00 -586.98 -412.73 6,030,904.92 544,738.59 2.86 230.54 MWD+IFR2+MS+sag(2) 3,239.99 56.14 235.04 2,934.67 2,887.17 -632.18 -474.94 6,030,859.35 544,676.66 4.20 230.33 MWD+IFR2+MS+sag(2) 3,334.30 58.51 235.29 2,985.58 2,938.08 -677.52 -540.10 6,030,813.62 544,611.79 2.52 228.51 MWD+IFR2+MS+sag(2) 3,428.97 59.88 235.20 3,034.06 2,986.56 -723.87 -606.90 6,030,766.87 544,545.28 1.45 226.54 MWD+IFR2+MS+sag(2) 3,523.63 65.26 233.25 3,077.65 3,030.15 -772.99 -675.02 6,030,717.34 544,477.47 5.97 226.03 MWD+IFR2+MS+sag(2) 3,617.82 65.87 232.45 3,116.61 3,069.11 -824.78 -743.36 6,030,665.14 544,409.44 1.01 227.53 MWD+IFR2+MS+sag(2) 3,712.88 64.80 232.68 3,156.28 3,108.78 -877.29 -811.96 6,030,612.22 544,341.17 1.15 229.47 MWD+IFR2+MS+sag(2) 3,806.68 64.86 232.33 3,196.18 3,148.68 -928.97 -879.31 6,030,560.14 544,274.14 0.34 231.47 MWD+IFR2+MS+sag(2) 3,901.26 64.94 231.80 3,236.30 3,188.80 -981.62 -946.86 6,030,507.08 544,206.92 0.51 234.14 MWD+IFR2+MS+sag(2) 3,995.68 64.53 232.07 3,276.60 3,229.10 -1,034.27 -1,014.09 6,030,454.03 544,140.02 0.51 237.00 MWD+IFR2+MS+sag(2) 4,090.44 64.40 231.23 3,317.45 3,269.95 -1,087.32 -1,081.15 6,030,400.58 544,073.29 0.81 240.28 MWD+IFR2+MS+sag(2) 4,184.25 64.17 231.16 3,358.15 3,310.65 -1,140.28 -1,147.01 6,030,347.22 544,007.76 0.25 244.20 MWD+IFR2+MS+sag(2) 4,278.15 63.94 231,59 3,399.23 3,351.73 -1,192.99 -1,212.98 6,030,294.12 543,942.12 0.48 247.85 MWD+IFR2+MS+sag(2) 4,372.60 63.46 226.45 3,441.10 3,393.60 -1,248.49 -1,276.87 6,030,238.24 543,878.57 4.90 254.97 MWD+IFR2+MS+sag(2) 4,466.21 62.39 222.41 3,483.72 3,436.22 -1,307.98 -1,335.22 6,030,178.40 543,820.59 4.01 268.60 MWD+IFR2+MS+sag(2) 4,561.79 61.35 216.85 3,528.81 3,481.31 -1,372.85 -1,388.96 6,030,113.21 543,767.25 5.24 289.28 M1ND+IFR2+MS+sag(2) 4,655.70 61.76 210.36 3,573.58 3,526.08 -1,441.57 -1,434.62 6,030,044.22 543,722.01 6.09 317.84 MWD+IFR2+MS+sag(2) 4,750.48 62.10 201.97 3,618.24 3,570.74 -1,516.54 -1,471.44 6,029,969.04 543,685.65 7.82 356.66 MWD+IFR2+MS+sag(2) 9/18/2015 12:39:OOPM Page 3 COMPASS 5000.1 Build 73 • • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 PB1 Survey Calculation Method: Minimum Curvature Design: MPL-46 PB1 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) (01100) (ft) Survey Tool Name 4,844.84 62.35 196.67 3,662.24 3,614.74 -1,595.29 -1,499.04 6,029,890.13 543,658.53 4.98 403.97 MWD+IFR2+MS+sag(2) 4,939.43 62.52 191.26 3,706.04 3,658.54 -1,676.62 -1,519,27 6,029,808.69 543,638.80 5.07 457.71 MWD+IFR2+MS+sag(2) 5,033.56 62.37 187.71 3,749.59 3,702.09 -1,758.91 -1,533.02 6,029,726.32 543,625.55 3.35 516.05 MWD+IFR2+MS+sag(2) 5,128.41 62.96 182.26 3,793.17 3,745.67 -1,842.81 -1,540.32 6,029,642.39 543,618.76 5.14 579.49 MWD+IFR2+MS+sag(2) 5,221.71 64.31 178.32 3,834.62 3,787.12 -1,926.38 -1,540.73 6,029,558.83 543,618.86 4.05 646.73 MWD+IFR2+MS+sag(2) 5,316.81 65.67 173.62 3,874.84 3,827.34 -2,012.31 -1,534.66 6,029,472.94 543,625.45 4.70 719.71 MWD+IFR2+MS+sag(2) 5,411.68 68.23 167.67 3,912.01 3,864.51 -2,098.38 -1,520.43 6,029,386.97 543,640.20 6.37 797.60 MWD+IFR2+MS+sag(2) 5,505.83 68.92 160.86 3,946.44 3,898.94 -2,182.68 -1,496.67 6,029,302.83 543,664.47 6.77 879.68 MWD+IFR2+MS+sag(2) 5,600.09 70.61 154.33 3,979.07 3,931.57 -2,264.37 -1,462.96 6,029,221.34 543,698.67 6.74 965.54 MWD+IFR2+MS+sag(2) 5,694.83 70.76 149.34 4,010.42 3,962.92 -2,343.16 -1,420.77 6,029,142.82 543,741.33 4.97 1,054.05 MWD+IFR2+MS+sag(2) 5,761.47 72.15 147.34 4,031.62 3,984.12 -2,396.93 -1,387.61 6,029,089.26 543,774.82 3.53 1,117.03 MWD+IFR2+MS+sag(2) 5,850.59 71.73 146.87 4,059.25 4,011.75 -2,468.08 -1,341.60 6,029,018.40 543,821.26 0.69 1,201.62 MWD+IFR2+MS+sag(2) 5,944.83 74.69 140.59 4,086.49 4,038.99 -2,540.75 -1,288.23 6,028,946.07 543,875.06 7.11 1,291.78 MWD+IFR2+MS+sag(2) 6,039.01 77.02 136.74 4,109.51 4,062.01 -2,609.29 -1,227.92 6,028,877.90 543,935.78 4.67 1,382.70 MWD+IFR2+MS+sag(2) 6,133.40 82.24 133.82 4,126.50 4,079.00 -2,675.22 -1,162.60 6,028,812.37 544,001.49 6.31 1,474.47 MWD+IFR2+MS+sag(2) 6,227.74 83.78 129.26 4,137.99 4,090.49 -2,737.29 -1,092.53 6,028,750.73 544,071.93 5.07 1,565.92 MWD+IFR2+MS+sag(2) 6,322.31 84.75 124.40 4,147.44 4,099.94 -2,793.67 -1,017.23 6,028,694.81 544,147.56 5.22 1,655.87 MWD+IFR2+MS+sag(2) 6,416.80 84.01 124.35 4,156.70 4,109.20 -2,846.77 -939.62 6,028,642.20 544,225.49 0.78 1,744.52 MWD+IFR2+MS+sag(2) 6,511.27 83.70 123.60 4,166.81 4,119.31 -2,899.26 -861.73 6,028,590.19 544,303.69 0.85 1,832.85 MWD+IFR2+MS+sag(2) 6,607.41 88.15 122.31 4,173.64 4,126.14 -2,951.41 -781.28 6,028,538.53 544,384.44 4.82 1,922.42 MWD+IFR2+MS+sag(3) 6,701.93 87,90 119.46 4,176.90 4,129.40 -2,999.89 -700.22 6,028,490.55 544,465.79 3.03 2,009.38 MWD+IFR2+MS+sag(3) 6,796.69 89.20 119.85 4,179.30 4,131.80 -3,046.76 -617.90 6,028,444.18 544,548.38 1.43 2,095.79 MWD+IFR2+MS+sag(3) 6,890.47 90.55 121.22 4,179,50 4,132.00 -3,094.40 -537.13 6,028,397.03 544,629.43 2.05 2,181.90 MWD+IFR2+MS+sag(3) 6,985.52 91.05 123.44 4,178.17 4,130.67 -3,145.23 -456.83 6,028,346.70 544,710.04 2.39 2,270.31 MWD+IFR2+MS+sag(3) 7,079.81 90.43 125.60 4,176.96 4,129.46 -3,198.65 -379.15 6,028,293.76 544,788.03 2.38 2,359.27 MWD+IFR2+MS+sag(3) 7,174.31 89.81 125.26 4,176.76 4,129.26 -3,253.44 -302.15 6,028,239.45 544,865.35 0.75 2,448.93 MWD+IFR2+MS+sag(3) 7,269.12 89.20 125.43 4,177.58 4,130.08 -3,308.28 -224.82 6,028,185.08 544,943.01 0.67 2,538.83 MWD+IFR2+MS+sag(3) 7,363.38 89.20 126.13 4,178.89 4,131.39 -3,363.39 -148.36 6,028,130.44 545,019.80 0.74 2,628.43 MWD+IFR2+MS+sag(3) 7,458.01 89.50 124.89 4,179.97 4,132.47 -3,418.35 -71.34 6,028,075.96 545,097.14 1.35 2,718.24 MWD+IFR2+MS+sag(3) 7,552.19 89.07 124.51 4,181.14 4,133.64 -3,471.96 6.09 6,028,022.82 545,174.88 0.61 2,807.20 MWD+IFR2+MS+sag(3) 7,646.35 89.07 125.14 4,182.67 4,135.17 -3,525.72 83.37 6,027,969.53 545,252.49 0.67 2,896.21 MWD+IFR2+MS+sag(3) 7,739.95 88.95 124.56 4,184.29 4,136.79 -3,579.20 160.17 6,027,916.53 545,329.60 0.63 2,984.69 MWD+IFR2+MS+sag(3) 7,835.20 89.26 122.84 4,185.78 4,138.28 -3,632.04 239.41 6,027,864.18 545,409.15 1.83 3,074.10 MWD+IFR2+MS+sag(3) 7,928.70 89.13 121.06 4,187.09 4,139.59 -3,681.51 318.73 6,027,815.19 545,488.76 1.91 3,160.84 MWD+IFR2+MS+sag(3) 8,024.43 90.12 123.79 4,187.72 4,140.22 -3,732.83 399.52 6,027,764.37 545,569.86 3.03 3,249.94 MWD+IFR2+MS+sag(3) 8,117.66 89.38 125.26 4,188.12 4,140.62 -3,785.67 476.33 6,027,712.00 545,646.98 1.77 3,337.91 MWD+IFR2+MS+sag(3) 8,213.21 87.96 124.72 4,190.34 4,142.84 -3,840.45 554.59 6,027,657.71 545,725.56 1.59 3,428.30 MWD+IFR2+MS+sag(3) 8,306.54 88.15 123.55 4,193.51 4,146.01 -3,892.79 631.79 6,027,605.84 545,803.07 1.27 3,516.11 MWD+IFR2+MS+sag(3) 8,400.37 89.94 123.59 4,195.07 4,147.57 -3,944.66 709.96 6,027,554.45 545,881.54 1.91 3,604.10 MWD+IFR2+MS+sag(3) 8,493.90 89.26 123.71 4,195.72 4,148.22 -3,996.49 787.81 6,027,503.10 545,959.71 0.74 3,691.88 MWD+IFR2+MS+sag(3) 9/18/2015 12:39:OOPM Page 4 COMPASS 5000.1 Build 73 IP • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 PB1 Survey Calculation Method: Minimum Curvature Design: MPL-46 PB1 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 8,589.77 88.83 124.73 4,197.32 4,149,82 -4,050.39 867.08 6,027,449.68 546,039.28 1.15 3,782.16 MWD+IFR2+MS+sag(3) 8,685.03 91.42 125.06 4,197.11 4,149.61 -4,104.88 945.20 6,027,395.67 546,117.73 2.74 3,872.24 MWD+IFR2+MS+sag(3) 8,779.35 94.89 125.37 4,191.92 4,144.42 -4,159.18 1,022.13 6,027,341.85 546,194.98 3.69 3,961.47 MWD+IFR2+MS+sag(3) 8,873.38 94.88 124.68 4,183.92 4,136.42 -4,212.95 1,098.85 6,027.288.55 546,272.02 0.73 4,050.14 MWD+IFR2+MS+sag(3) 8,968.22 94.88 124.98 4,175.85 4,128.35 -4,266.92 1,176.42 6,027,235.06 546,349.91 0.32 4,139.48 MWD+IFR2+MS+sag(3) 9,061.91 91.61 124.29 4,170.55 4,123.05 -4,320.08 1,253.37 6,027,182.38 546,427.17 3.57 4,227.79 MWD+IFR2+MS+sag(3) 9,156.07 90.86 126.06 4,168.52 4,121.02 -4,374.31 1,330.32 6,027,128.62 546,504.44 2.04 4,316.97 MWD+IFR2+MS+sag(3) 9,250.42 88.76 125.72 4,168.83 4,121.33 -4,429.61 1,406.75 6,027,073.78 546,581.20 2.25 4,406.72 MWD+IFR2+MS+sag(3) 9,345.17 89.88 125.14 4,169.95 4,122.45 -4,484.54 1,483.95 6,027,019.34 546,658.72 1.33 4,496.60 MWD+IFR2+MS+sag(3) 9,439.44 90.99 126.62 4,169.24 4,121.74 -4,539.78 1,560.32 6,026,964.56 546,735.42 1.96 4,586.26 MWD+IFR2+MS+sag(3) 9,533.82 91.30 125.46 4,167.35 4,119.85 -4,595.30 1,636.62 6,026,909.51 546,812.05 1.27 4,676.10 MWD+IFR2+MS+sag(3) 9,627.84 92.59 124.59 4,164.16 4,116.66 -4,649.23 1,713.57 6,026,856.06 546,889.32 1.65 4,765.04 MWD+IFR2+MS+sag(3) 9,722.55 92.66 123.69 4,159.82 4,112.32 -4,702.33 1,791.88 6,026,803.44 546,967.94 0.95 4,854.10 MWD+IFR2+MS+sag(3) 9,816.88 90.00 123.53 4,157.63 4,110.13 -4,754.52 1,870.41 6,026,751.73 547,046.78 2.82 4,942.57 MWD+IFR2+MS+sag(3) 9,911.26 84.87 123.15 4,161.86 4,114.36 -4,806.32 1,949.15 6,026,700.41 547,125.82 5.45 5,030.85 MWD+IFR2+MS+sag(3) 10,005.66 84.81 122.93 4,170.35 4,122.85 -4,857.58 2,027.96 6,026,649.64 547,204.94 0.24 5,118.73 MWD+IFR2+MS+sag(3) 10,100.37 83.26 123.15 4,180.19 4,132.69 -4,908.94 2,106.92 6,026,598.76 547,284.20 1.65 5,206.78 MWD+IFR2+MS+sag(3) 10,194.89 83.32 123.48 4,191.23 4,143.73 -4,960.50 2,185.37 6,026,547.69 547,362.95 0.35 5,294.69 MWD+IFR2+MS+sag(3) 10,289.13 84.68 125.24 4,201.08 4,153.58 -5,013.40 2,262.73 6,026,495.27 547,440.63 2.35 5,383.03 MWD+IFR2+MS+sag(3) 10,383.33 84.86 125.33 4,209.67 4,162.17 -5,067.58 2,339.31 6,026,441.55 547,517.52 0.21 5,471.96 MWD+IFR2+MS+sag(3) 10,478.02 87.16 126.60 4,216.26 4,168.76 -5,123.05 2,415.76 6,026,386.55 547,594.30 2.77 5,561.85 MWD+IFR2+MS+sag(3) 10,569.19 87.78 125.87 4,220.28 4,172.78 -5,176.89 2,489.22 6,026,333.17 547,668.08 1.05 5,648.65 MWD+IFR2+MS+sag(3) 10,663.75 88.45 124.85 4,223.39 4,175.89 -5,231.58 2,566.29 6,026,278.95 547,745.48 1.29 5,738.28 MWD+IFR2+MS+sag(3) 10,759.28 90.12 123.05 4,224.59 4,177.09 -5,284.93 2,645.53 6,026,226.09 547,825.03 2.57 5,828.09 MWD+IFR2+MS+sag(3) 10,855.66 90.80 121.76 4,223.81 4,176.31 -5,336.57 2,726.89 6,026,174.95 547,906.70 1.51 5,917.79 M1ND+IFR2+MS+sag(3) 10,950.04 90.12 120.54 4,223.06 4,175.56 -5,385.39 2,807.66 6,026,126.63 547,987.75 1.48 6,004.86 MWD+IFR2+MS+sag(3) 11,044.50 90.93 120.78 4,222.19 4,174.69 -5,433.56 2,888.91 6,026,078.96 548,069.29 0.89 6,091.68 MWD+IFR2+MS+sag(3) 11,136.92 87.59 121.65 4,223.38 4,175.88 -5,481.44 2,967.93 6,026,031.56 548,148.59 3.73 6,176.96 MWD+IFR2+MS+sag(3) 11,232.36 90.62 123.89 4,224.87 4,177.37 -5,533.09 3,048.16 6,025,980.41 548,229.12 3.95 6,265.98 MWD+IFR2+MS+sag(3) 11,324.95 92.59 123.61 4,222.28 4,174.78 -5,584.50 3,125.11 6,025,929.46 548,306.38 2.15 6,352.89 MWD+IFR2+MS+sag(3) 11,421.26 90.74 121.93 4,219.48 4,171.98 -5,636.61 3,206.05 6,025,877.86 548,387.62 2.59 6,442.71 MWD+IFR2+MS+sag(3) 11,515.99 90.49 119.69 4,218.47 4,170.97 -5,685.12 3,287.40 6,025,829.84 548,469.26 2.38 6,529.87 MWD+IFR2+MS+sag(3) 11,610.29 90.25 117.93 4,217.86 4,170.36 -5,730.56 3,370.03 6,025,784.91 548,552.15 1.88 6,615.30 MWD+IFR2+MS+sag(3) 11,704.57 93.28 122.22 4,214.95 4,167.45 -5,777.77 3,451.55 6,025,738.21 548,633.95 5.57 6,701.51 MWD+IFR2+MS+sag(3) 11,799.11 93.83 124.39 4,209.09 4,161.59 -5,829.58 3,530.40 6,025,686.88 548,713.11 2.36 6,789.86 MWD+IFR2+MS+sag(3) 11,887.88 92.34 124.90 4,204.31 4,156.81 -5,879.97 3,603.33 6,025,636.94 548,786.33 1.77 6,873.56 MWD+IFR2+MS+sag(3) 11,982.72 90.37 125.95 4,202.07 4,154.57 -5,934.92 3,680.58 6,025,582.46 548,863.91 2.35 6,963.51 MWD+IFR2+MS+sag(3) 12,077.11 88.45 128.40 4,203.04 4,155.54 -5,991.95 3,755.78 6,025,525.90 548,939.44 3.30 7,053.91 MWD+IFR2+MS+sag(3) 12,195.00 88.45 128.40 4,206.23 4,158.73 -6,065.15 3,848.13 6,025,453.27 549,032.23 0.00 7,167.50 PROJECTED to TD 9/18/2015 12:39:00PM Page 5 COMPASS 5000.1 Build 73 0 • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPL-46 Project: Milne Point TVD Reference: As-Built MPL-46 @ 47.50usft Site: M Pt L Pad MD Reference: As-Built MPL-46 @ 47.50usft Well: MPL-46 North Reference: True Wellbore: MPL-46 PB1 Survey Calculation Method: Minimum Curvature Design: MPL-46 PB1 Database: Sperry EDM-NORTH US+CANADA brian.wheeler@halliburto 01,=.1.....=,....., Checked By: n.com �p=�.�-�« Approved By: carYlayior@hauiburtoacom ,:.�,,,,,„.... Date: 9/18/2015 12:39:00PM Page 6 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. Milne Point Unit,L-46 Date 25-Aug-15 County North Slope Borough State Alaska Supv. Sloan Sunderland/Doug Yessak CASING RECORD TD 6630.00 Shoe Depth: 6620.16 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 95/8 TC-II DHP 1.85 6,620.16 6,618.31 1int _ 9 5/8 40 L-80 TC-II 36.61 6,618.31 6,581.70 Flt Clr _ 9 5/8 TC-II DHP 1.21 6,581.70 6,580.49 11nt 9 5/8 40 L-80 TC-II _ 36.62 6,580.49 6,543.87 Pup XO 9 5/8 40 L-80 TC-II 16.36 6,543.87 6,527.51 BFL 9 5/8 40 L-80 BTC 1.25 6,527.51 6,526.26 Pup XO 9 5/8 40 L-80 TC-II 16.61 6,526,26... 6,509.65 103_Into _ 95/8 40 L-80 TC-II 4,138.41. 6,509.62,371.24 Pup XO 9 5/8 40 L-80 TC-II 17.06 2,371.24 2,354.18 ES CMT 9 5/8 40 L-80 BTC _ 2.84 2,354.18 2,351.34 Pup XO _ 9 5/8 40 L-80 TC-II 16.60 2,351.34 2,334.74 57 into _ 9 5/8 TC-II 2,301.37 2,334.74 33.37 Hgrw/pup 95/8 40 L-80 TC-II Seaboard 2.62 33.37 30.75 RKB _ 9 5/8 BTC 30.75 30.75 0.00 Totals 162 kits Csg Wt.On Hook: 115 Type Float Collar: Model 402 No.Hrs to Run: 12 Csg Wt.On Slips: 85 Type of Shoe: Bull Nose Casing Crew: VVFD Fluid Description: 9.3 ppg Spud Mud, YP 24 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 FC Joint, 1 centralizers every other jnt to 15, Plus 3 above and below the ES Cmt Tool.20 Total CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 65 Lead Slurry Type: Extended Density(ppg) 11.7 Volume pumped(BBLs) 241 Mixing/Pumping Rate(bpm): 3 Tail Slurry Type: Swift Chem Stage 1 Density(ppg) 15.8 Volume pumped(BBLs) 79.3 Mixing/Pumping Rate(bpm): 3 N Post Flush(Spacer) L,> Type:Fresh Water Density(ppg) 8.3 Rate(bpm): 5 Volume: 20 ri Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 6 Volume(actual/calculated): 469/477 FCP(psi): 1300 Pump used for disp: Halliburton Plug Bumped? x Yes No Bump press 1900 Casing Rotated? Yes X No Reciprocated? _Yes X No %Returns during job 100 Cement returns to surface? x Yes No Spacer returns? X Yes_No Vol to Surf 30 Cement In Place At: 10:08 Date: 8/25/2015 Estimated TOC: 2,350 Method Used To Determine TOC: ES Cmt tool Preflush(Spacer) Type: Tuned Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 34.5 Lead Slurry Type: Permafrost L Stage 2 Lead Density(ppg) 10.7 Volume pumped(BBLs) 224 Mixing/Pumping Rate(bpm): 3 Tail Slurry w Type: Swift Chem-Stage 2 Lead cir'F Density(ppg) 15.8 Volume pumped(BBLs) 55.5 Mixing/Pumping Rate(bpm): 3 0 Post Flush(Spacer) Type: Density(ppg) Rate(bpm): Volume: LU Displacement: Type: Spud Mud Density(ppg) 9.3 Rate(bpm): 4 Volume(actual/calculated): 166/172 FCP(psi): 650 Pump used for disp: Halliburton Plug Bumped? X Yes No Bump press 2000 Casing Rotated? Yes No Reciprocated? Yes No %Returns during job 100 Cement returns to surface? x Yes_No Spacer returns? x Yes_No Vol to Surf: 182 Cement In Place At: 4:39 Date: 8/25/2015 Estimated TOC: 0 Method Used To Determine TOC: Returns to surface WELLHEAD Make Seaboard Type 3000 psi Wellhead Serial No. Size W.P. Test Head To PSIG MIN OK Remarks: We finished both stages with cmt returned to surface. • . MPL-46 Days vs Depth FINAL 0 500 --1- —MPL-46 Actual -- 1000 MPL-46 Plan 1500 2000 2500 3000 3500 .._...__ 4000 __ _ 4500 5000 _ 5500 —. _ 6000 F s 6500 — a O 7000 v 7500 w 8000 \.\\\°-\\ 2 8500 9000 - 9500 10000 10500 11000 11500 12000 12500 -I_-- 13000 13500 14000 14500 t — 0 5 10 15 20 25 30 35 Days 10/14/2015 3:05 PM • S MPL-46 MW vs Depth 0 MPL-46 Plan 1000 MPL-46 Actual 2000 3000 4000 5000 L a 6000 ea cu 7000 8000 9000 10000 11000 - 12000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) 215 .18 • • 26350 Maile Sweigart 2 6 7 7 7 Alaska North Slope Team Hilcorp Alaska, LLC 3800 Centerpoint Drive, Ste 1400 Anchorage,Alaska 99503 :uu*kii.LI(, Office: 907.777.8473 msweigart@hilcorp.com DATA LOGGED \0/2'/20155 M. K. BENDER DATE 10/13/15 RECEIVED To: Alaska Oil & Gas Conservation Commission OCT 1 3 215 Makana Bender Natural Resource Technician AOGCC 333 W 7th Ave Ste 100 AOGCC Anchorage, AK 99501 DATA TRANSMITTAL MPL-49 11(D E log data Prints MPL-46: DGR - ADR — EWR -Inverted/Reverted Sections 2" and 5"TVD 26350 ROP - DGR - ADR — EWR - Horizontal Presentation 2" and 5" MD Prints MPL-46PB1: DGR - ADR — EWR -Inverted/Reverted Sections 2" and 5"TVD 2 6 7 7 7 ROP - DGR - ADR — EWR- Horizontal Presentation 2" and 5" MD CD 1 : MPL-46 �e. Date modified CGM 9/28/2015 10:59 AM Definitive Surrey 9/28/2015 10:59 AM DLIS+LAS 9/28/2015 10:59 AM EMF 9/28/2015 10:59 AM PDF 9/28/2015 10:59 AM TIFF 9/28/2015 11:00 AM Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 8/�✓� Date: • . 11 51 18 11 Maile Sweigart 1 6 3 5 0 Alaska North Slope Team 26 7 7 7 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Ste 1400 Anchorage,Alaska 99503 ii,!."'i' 11 .I. LI I Office: 907.777.8473 msweigart@hilcorp.com MPL-46PB1 1:=,m€ Date modified aeD C G M 10/8/2015 12:25 PM iii Definitive Survey 10/8/2015 12:25 PM RECEIVED T. DLIS+LAS 10/9/20152:51 PM OCT 1 3 2015 , ,,, EMF 10/8/2015 12:25 PM A PDF 10/8/2015 12:25 PM AOGCC TIFF 10/8/2015 12:26 PM Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: tiOF ray, wP V/7, s THE STATE• Alaska Oil and Gas ofA LA S KA Conservation Commission z ,_�^_ 333 West Seventh Avenue voir -,*;. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF 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: Milne Point Field, Schrader Bluff Oil Pool, MPU L-46 Hilcorp Alaska, LLC Permit No: 215-118 Surface Location: 3303' FSL, 4733' FEL, SEC. 8, T13N, R10E, UM, AK Bottomhole Location: 1699' FSL, 338' FWL, SEC. 16, T13N, R10E, UM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development 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 PfFoerster Chair DATED this 13 day of July, 2015. RECEIVED STATE OF ALASKA ACA OIL AND GAS CONSERVATION COMMlJN JUL 0 6 2015 PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil 0 Service- Winj ❑ Single Zone 0 , 1c.Specify if well is proposed or: Drill ' 0 Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ _ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 i Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC • Bond No. 022035244 ' MPU L-46 3.Address: 6. Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 13,193' • TVD: 4,148' • Milne Point Unit 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Schrader Bluff Oil Pool Surface: 3303'FSL,4733'FEL,Sec 8,T13N, R10E,UM,AK ' p6., ;/p35-‘44g ADL 025509(TPH) () IS Top of Productive Horizon: 8. Land Use Permit: ) 13.Approximate Spud Date: 121'FSL, 148'FWL,Sec 8,T13N, R10E,UM,AK N/A 8/4/2015 Tk'LTotal Depth: 9.Acres in Property: 14. Distance to Nearest Property: 1699'FSL,338'FWL,Sec 16,T13N,R10E, UM,AK • 53'3-- (:,....i --7-3 10,616'to Unit Boundry 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 47 feet 15. Distance to Nearest Well Open Surface: x-545108.08 y- 6031494.52 Zone-4 GL Elevation above MSL: , 17 feet to Same Pool: -1,000'from L-49 16.Deviated wells: Kickoff depth: _251 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: ,90 degrees Downhole: 1853 psi 4 Surface: 1439 psi 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) Stg#1 Lead 1338 ft3/Tail 445 ft3 12-1/4" 9-5/8" 40# L-80 TC-II 6,585' 0 0 6,585' 4,148' Stg#2 Lead 1756 ft3/Tail 314 ft3 7-5/8" 29.7# L-80 VAM SLIJ-II 6,385' 0 0 6,385' 4,148' 8-1/2" 5-1/2" 17# L-80 DWC/CHT 6,815' 6,385' 4,147' 13,200' 4,148' Cmntless Prod(Slotted w/Swell Pkr) 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 0 BOP Sketch p Drilling Program 0 Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirementts 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luke Keller Email Ikeller@hilcorp.com Printed Name Luke Keller Title Drilling Engineer Signature / Phone 777-8371 Date 7- G- -2c)/X-- Commission Use Only Permit to Drill API Number: Permit Approval ' See cover letter for other Number: Y�- l I 50- +f- ' . i-00 -0O Date: t requirements. r - Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: ,U,( Other: ` 2 000 es, aee S? Samples req'd: Yes❑ Ma' Mud log req'd:Yeas❑ Na[}r J ( /A ‘--7.----;_ t--- __._ H2S measures: Yes[' Na❑ Directional svy req'd:YessZ Na❑ z_. Ob PS" . k-' GSt Spacing exception req'd: Yes;❑ NI.R'. Inclination-only svy req'd:Yes❑ Na[f / (2 e-d4- & P ``mss+- c2 / APPROVED BY / / Approved by: - /0 f / COMMISSIONER THE THE COMMISSION Date: 7 - /3 r .- iF 411 c Submit Form and Form 10-401(r �TF� rritevised 10/2012) a`i for 24 months from the date of approvalAAC 25.005(g)) Attachments in Duplicate 14 • • Hilcorp Luke Keller Hilcorp Alaska, LLC Energy Company Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 7/6/2015 Email lkeller@hilcorp.com Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 RECEIVED Re: MPL-46 Permit to Drill JUL 0 6 2015 AOGCC Dear Commissioner, MPU L-46 is a grassroots ESP producer planned to be drilled in the Schrader Bluff OA sand. L-46 is part of a (5)well pilot program targeting the OA sand. Each producing lateral will have water injection support on either side. . The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. A lateral section will then be drilled in the OA sand. A slotted liner will be run in the open hole section and the well produced with an ESP assembly. Drilling operations are expected to commence approximately August 4th, 2015. 1 Nordic Calista Rig#3 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, /66(.....-- Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • • Hilcorp Alaska, LLC Milne Point Unit (MPU) L-46 Drilling Program Version 1 April 29th, 2015 • Milne Point Drilling Procedure Hilcorp Energy Compury 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 System 10 11.0 Drill 12-1/4"Hole Section 13 12.0 Run 9-5/8" Surface Casing 17 13.0 Cement 9-5/8"Surface Casing 23 14.0 BOP N/U and Test 28 15.0 Drill 8-1/2"Hole Section 29 16.0 Run 5-1/2"Production Liner 34 17.0 Run ESP assy. 38 18.0 RDMO 39 19.0 Diverter Schematic 40 20.0 BOP Schematic 41 21.0 Wellhead Schematic 42 22.0 Days Vs Depth 43 23.0 Formation Tops 44 24.0 Anticipated Drilling Hazards 45 25.0 Nordic#3 Rig Layout(Drillers Side) 47 26.0 Nordic#3 Rig Layout(Well End&Top View) 48 27.0 FIT Procedure 49 28.0 Choke Manifold Schematic 50 29.0 Casing Design Information 51 30.0 8-1/2"Hole Section MASP 52 31.0 Spider Plot(NAD 27)(Governmental Sections) 53 32.0 Surface Plat(As Built)(NAD 27) 54 33.0 Offset MW vs TVD Chart 55 34.0 Drill Pipe Information 5" 19.5#S-135 DS-50 56 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well MPU L-46 Pad Milne Point"L"Pad Planned Completion Type ESP on 2-7/8"Production Tubing Target Reservoir(s) Schrader Bluff OA Sand Planned Well TD, MD/TVD 13,193' MD/4,148' TVD PBTD, MD/TVD 13,190' MD/4,148' TVD Surface Location(Governmental) 3,303' FSL,4,733' FEL, Sec 8, T13N, R10E,UM,AK Surface Location(NAD 27) X=545,148.08 Y=6,031,494.52 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 121'FSL, 148'FWL, Sec 8,T13N, R10E,UM,AK TPH Location(NAD 27) X=544779,Y=6028310.8 TPH Location(NAD 83) BHL(Governmental) 1699'FSL, 338' FWL, Sec 16, T13N, R10E, UM,AK BHL(NAD 27) X=550283.8,Y=6024644.5 BHL(NAD 83) AFE Number 1511124 AFE Drilling Days 15 days AFE Completion Days 4 days AFE Drilling Amount $4,137,342.00 AFE Completion Amount $1,155,100.00 AFE Facility Amount $431,000.00 Maximum Anticipated Pressure (Surface) 1439 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1853 psig Work String 5" 19.5# S-135 DS-50(Weatherford Rental) KB Elevation above MSL: 30 ft+ 17 ft=47 ft GL Elevation above MSL: 17 ft BOP Equipment 11"x 5M Annular, (3)ea 11"x 5M Rams Page 2 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Emily Company Changes to Approved Permit to Drill Date: 4-29-2015 Subject Changes to Approved Permit to Drill for MPU L-46 File#: MPU L-46 Drilling and Completion Program Any modifications to MPU L-46 Drilling& Completion Program will be documented and approved below_ Changes to an approved APD will be communicated to the AOGCC. Sec ' Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole OD(in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section _ (in) ; OD(in) (#/ft) (psi) (psi) (k-lbs) Cond 20" 19.25" - - 78.6 A-53 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.235" 40 L-80 TC-II 5,750 . 3,090 916 7-5/8" 6.82" 6.75" 7.711" 29.7 L-80 VAM 6,890 . 4,790 473 SLIJ-II 8-1/2" 5-1/2" 4.892" 4.767" 6.05" 17 L-80 DWC/C 7,740 . 7,100 397 HT 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn M/U M/U Tension Section (in) (in) (#/ft) (Min) (Max) (k-lbs) All 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 May, 2015 • Milne 1 Drilling ProcedurePointUnit -46 Hilcorp Energy Company 5.0 Internal Reporting Requirements 18.1 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. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 18.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com and cdinger@hilcorp.com 18.3 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. 18.4 EHS Incident Reporting • Health and safety:Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drlg Manager&Drlg Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 18.5 Casing Tally • Send final"As-Run"Casing tally to lkeller@hilcorp.com and cdinger@hilcorp.com 18.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and cdinger@hilcorp.com 18.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Paul Mazzolini 907.777.8369 907.317.1275 pmazzolini@hilcorp.com Drilling Engineer Luke Keller 907.777.8395 832.247.3785 Ikeller@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Keith Elliot 907.777.8355 832.233.5855 kelliott@hilcorp.com Drlg Environmental Coord Julieanna Orczewska 907.777.8444 907.715.7060 iorczewska@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 jiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 May, 2015 • • II Milne Point Unit L-46 Drilling Procedure HIlcorp Energy Company 6.0 Planned Wellbore Schematic AFE No. Well Name: KB: 30 ft AGL 1511124 Milne Point Unit(MPU)L-46 GL-I-RKB 17 ft+30 ft=47 ft API# AFE 1NELLBORE DESIGN Proposed TD: 13,193' Permit No. Proposed TVD: 4.148' __ Geologic Information Wellbore Information Casing Irfo!Mud Info/hole Size I Cement Specs Mud Program SS TVD FM Llthology Conductor ace-mmres,nerr 34"x 20"Insulated conductor(Pre-set)to 80'BGL(110'RKB) Interval: V Inner sleeve.20"x 0375'Wall 78.6#.A-53.ERW,PE Surface hole c N ar Exterior Jacket:34"x 0.344"Wall,123#.A-139,Grade B spiral.PE Mud Type. E Fresh Water+'Native -E w Surface Casing WOW Range. ; ,, 6 o 9-5/8"40#L-80 TC-Il set at 6585'MDI 4148'TVD 8.8-0.2_ o g e 34 6 ESurface Casing Cement w 8 3 1st Stage n d m 60 bbls 10.5 ppg Tuned spacer Ill m 1 Lead:(50%OH Excess)ARCT}CCEM G 10.7 ppg c = Tail:(50%OH Excess)SWIFTCEM 15.8 ppg c E o -0rF 2nd stage: 1750' 60 bbls 10.5 ppg Tiered spacer Ill t Stage Collar Lead:(Until returns at surface)ARCTICCEM 10.7 ppg m 2300'MD/ Tail:SWIFTCEM 15.8 ppg c c 2 Z. y Y Production Liner -' 5-1/2"17#L-80 DWC/C HT Slotted liner @ 13.193'MD!4.148'TVD - J N D- - Tieback r` c m 7-5/8"29.7#L-80 SLIJ-ll a 6385'MD/4148'TVD c r3 8 �' �w✓ ry o /►ylv- Production Tubing `o # i y` 2.718"6.0 L-80 8RD EUE 0o1.9R N o cp E V N C '3500' u 3 g of '',(., rrIlk K-sands Coarse sand,silty shale,better BP Interval: UGNU developed Bulkt Sean Production Hae 1-Sands intervening shales Slotted liner Mud Tvpa_ -4000' M-sands in the L and M .4 / Baradril-N Inn N-sands Continued layering as I, • ''" Weight Range: Schrader in Ugnu,more �'/iy� �" 8.9-9.2 ppg 0-sands condensed with occ. coal _.. .,. ,.� -4300' I2- Pei) Fir Liner Top Packer@ EPAW 6385'MD Page 6 Version 1 May, 2015 Milne Point Unit 1-46 11 Drilling Procedure Hilcorp Energy ComP AY 7.0 Drilling / Completion Summary MPU L-46 is a grassroots ESP producer planned to be drilled in the Schrader Bluff OA sand. L-46 is part of a(5)well pilot program targeting the OA sand. Each producing lateral will have water injection support on either side. The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. A lateral section will then be drilled in the OA sand. A slotted liner will be run in the open hole section and the well produced with an ESP assembly. Drilling operations are expected to commence approximately August 4th,2015. Nordic Calista Rig#3 will be used to drill and complete the wellbore. Surface casing will be run to 6,585' MD/4,148' TVD and cemented to surface via a 2 stage primary cement job. 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 operations above the UGNU formation (3500' TVD) will be hauled to the Milne Point"A"pad temporary disposal site for storage until the Milne Point G&I facility is up and running. Waste and mud generated after penetrating the UGNU formation will be hauled to the BP G&I facility at Prudhoe Bay. General sequence of operations: 1. MOB Nordic Rig#3 to well site. 2. N/U 21-1/4" conductor and 16" diverter line. 3. Drill 12-1/4" hole to TD of surface hole section. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U & test 11"x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 5-1/2" slotted liner. 6. Run 7-5/8" Tieback. 7. Run ESP assy. 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR+Res 2. Production Hole: No mud logging. On site geologist. LWD: GR+ADR(For geo-steering) Page 7 Version 1 May,2015 '/ • • Milne Point Unit L-46 Drilling Procedure Hilcorp Enemy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling and completion of MPU L-46 Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 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: • There are no variance requests at this time. Page 8 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter w/ 16"diverter line Function Test Only • 11"x 5M Hydril Annular BOP • 11"x 5M Shaffer Double Ram Initial Test:250/3000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 8-1/2" • 11"x 5M Hydril Single Ram • 3"x 5M Choke Line Subsequent Tests: • 3"x 5M Kill line 250/2500 • 3"x 5M Choke manifold(10M Hydraulic remote Choke (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Hydril, 165 gal, 6 station accumulator w/dual electric and air pumps, w/ 1 (ea) electric over hydraulic remote control panel at the driller station. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Tertiary pressure is provided by air pumps. 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@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format:http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 1 May,2015 S • 11 Milne Point Unit 1-46 Drilling Procedure Hilcorp Emir CoelP.nr 9.0 R/U and Preparatory Work 9.1 Set insulated 34" x 20" conductor at 80' below ground level (110' RKB). 9.2 Dig out and set impermeable cellar. 9.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.4 Install Seaboard slip-on 16-3/4" 3M"A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.5 Insure (2) 3"threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. These will be used to take cement returns to the cellar during the surface cmt job, and also to wash out the diverter and hanger in preparation for running the pack-off. 9.6 Level pad and ensure enough room for layout of rig footprint and R/U. 9.7 Rig mat over footprint of rig. 9.8 Confirm that the rig is over the appropriate well slot. 9.9 MIRU Nordic #3. 9.10 Mud loggers WILL NOT be used on either hole section. 9.11 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 9.12 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.13 Install 5-1/2" liners in mud pumps. • Continental EMSCO F-1000 mud pumps are rated at 3500 psi (100%)/354 gpm(120 spm @ 95% eff)with 5-1/2" liners. 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M diverter System (Diverter Schematic at Sec 18 at back of program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA 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). • Diverter line must be 75 ft from nearest ignition source Page 10 Version 1 May,2015 • S Milne Point Unit L-46 1111 Drilling Procedure Hilcorp energy Company • Place drip berm at the end of diverter line. 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._ 4-:. 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 7-i • 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. 10.5 Pad Drawing N 2000 7' a - a M PU •E MON t N L PAD o •• N 1500 ■ ■ I L ■ ■ r■■ ■a<wr� ; '11 N 1000 ❑ L MON L2S I � Page 11 Version 1 May, 2015 • • 11 Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 10.6 Rig& Diverter Orientation on "L"pad: • • I • „_„......4, L, , r r_ 1 -L-50 �L-48III -L-44 �1 �. = 1__ �� — I ,„,--43 h Metier Lino I 7 a i ';r i ,1 ',- il III .W.i 4,,„ 11:4 1i !? 1tia `$—a,‘. i11 d1 e I 111 lyti, , I ' I f Page 12 Version 1 May,2015 s II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" 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. • Ensure Gyro MWD is R/U and operational. Be sure to run a UBHO sub so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135. • Run a solid float in the surface hole section. , 11.2 12-1/4" BHA (GR+ Res LWD and PWD planned in surface hole): liHAL"I..IBURTON ['WELL INFORMATION 411111Created On:May 01 2015 BHA TallyCustomer : Hilcorp Engergy Well Name : MPL-1 Job Number : -XX- Drilistring Rig Name : Nordic 3 IADC Rig BHA# Field Name : Milne Point Run# 103 Country : USA COMPONENT DATA Item O itt ugs Weight )qp enginIIR +cumutbt # Description Serial Number Connection . (in) , (in) ' (in) (Ibp() (ft) Length (ft) nil PDC 8.000 3.000 12.250 14722 P 6-5/8"REG 1.10 1.10 © 8"SperryOt Lobe 413-5.3 s1g 8.000 5.000 103.09 B 6-5/8"REG 31.47 32.57 - Stabilizer - _ 12.125 _--_ © Float Sub 8.000 2.880 149.10 B 6-518"REG 2.40 34.97 0 Stabilizer 8.000 3.000 10.250 147.22 B 6-5/8"REG 6.00 40.97 0 8'DM Collar 8.000 3.500 147.40 B 6-5/8"REG 9.20 50.17 O 8"DGR Collar 8.000 1.920 142.70 B 6-5/8"REG 4.55 54.72 MI 8"EWR-P4 Collar 8.000 1.985 151.00 B 6-5i8"REG 12.19 66.91 8 8"HCIM Collar 8.000 1.920 149.90 B 6-518"REG 4.97 71.88 9 8"POS PULSER 8.000 4.000 145.20 B 6-5/8"REG 15.44 87.32 10 Orienting Sub UBHO 8.000 2.875 149.18 B 6-518"REG 2.50 89.82 ® NM Flex Collar 8.000 2.813 150.13 B 6-5/8"REG 31.00 120.82 ® NM Flex Collar 8.000 2.813 150.13 B 6-518"REG 3100 151.82 ® NM Flex Collar 8.000 2.813 150.12 B 6-5/8"REG 31.00 182.82 ICI 8jts x 5"X 3'HWDP#49.3-NC50(IF)- 5.000 3.000 49.30 240.00 422.82 ® Jar 7.500 2.813 129.38 B 4-112"IF 35.00 457.82 m12jts x 5'X 3"H FDP#49.3-NC50 5.000 3.000 49.30 360.00 817.82 s MSS: 817.82 Page 13 Version 1 May, 2015 • ! • Milne Point Unit L-46 Drilling Procedure Hilcorp 11.3 Primary Bit: 12-1/4" {311mm) QHCIGRC PRODUCT SPECIFICATIONS , 411/111114 IADC Code 117W 114 Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33° tr low Offset(1/16") 6 rimp, Jet Nozzle Types Standard 83244 Extended 302447 Center Jet Of Center Jetted)501813 T.J.Connection 6-5/8"(API Reg.) Recommended Make-Up Torques 28000132000 Ftslbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) x . Bit Breaker(Mat.#/Legacy#) 515353/506463 PRODUCT FEATURES • New patented Diamond*"Claw/tooth bit design. • Tungsten carbide`surf inserts in gage teeth for added gage yip, i protection. Newly formulated,proprietary hardfacing on cutting structure and ti gage maximizes carbide and diamond volume for ultimate wear +" #' resistance. 4 w • Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque- . QuadPackt Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems . Dual seal/dual compensation bearing system containing dual seals. dual independent pressure compensators,and a dual grease formulation. • The latest OCP seal technology designed with the highest contact pressures on the outside edges of the seal where it is needed most. Material II740990 helps keep contaminants out extending bearing life. `Calculations based on recommendations fmm API and tool-joint manufacturers. C 2014 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.hailiburton.com 11.4 5" Workstring, HWDP, and Jars will come from Weatherford. 11.5 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 6,585' MD/4,148' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. Page 14 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. ESP equipment can be damaged if run through high dog legs. Keep DLS <6 deg/ 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 600 - 650 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • Ensure to leave a"Pump Tangent" section that is approx. 300' long in the directional plan. The ESP will need a straight section to sit. This will occur very near TD of the hole section. • Make wiper trips every 2000' 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 just into the Schrader Bluff OA sand. Geologists and Drilling Engineers will help adjust well path to ensure well is landed correctly. • Take MWD surveys every stand drilled (60' intervals). • Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas cut mud before continuing to drill. There have been no indications of hydrates on any of the "L"pad wells to date. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. Page 15 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 11.7 12-1/4"hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. • PVT System: MD Totco 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. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM(10 ppb total)BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5—9.0 range with caustic soda. Daily additions of ALDACIDE G/X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20 (check with the cementers to see what YP value they have targeted). System Type: 8.8—9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths /Density Viscosity _ Plastic Viscosity Yield Point API FL pH 80-6585' 8.8—9.2 85-250 20-40 25-75 <10 8.5—9.0 System Formulation: Gel + FW 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—9.2 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb Page 16 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 20" conductor shoe. 11.9 Should backreaming be necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 3 —4 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (600—700 gpm), and maximize rotation. • Pull slowly, 5— 10 ft/minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.10 TOH with the drilling assy, handle BHA as appropriate. 11.11 No open hole logging program planned. 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 Make a dummy run with the 9-5/8" casing hanger. 12.3 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8"TC-II x DS50 XO on rig floor and M/U to FOSV. aC • Consider R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" 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. 12.4 P/U shoe joint, visually verify no debris inside joint. 12.5 Continue M/U & thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on(thread locked). Install (2) centralizers on shoe joint over stop collars 10' from each end. • (1) Joint with float collar bucked on pin end &thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure bypass baffle is correctly installed on top of float collar. Page 17 Version 1 May, 2015 • S Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company Bypass Baffle This end up. 01MA • (1) Joint with Halliburton bypass baffle adapter bucked on pin& threadlocked. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 18 Version 1 May, 2015 • II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 12.6 Float equipment and Stage tool equipment drawings: "A Overall Length I. Type H ES Cementer B C Isf Pa[t No. r-^.ID After 0,flout SO No. - Max.Tcoi GD MIN a i D Hi&orp ES-II Running Order �' Opening Seal ID A I Closing Sleeve No.Shear Pins E Closing Seat ID 1I D"- Il Opening Sleeve C No.Shear Pins plug Set i ES-II Cementer � ES Cementer Part No. ' Depth 1 I SO No. / Ir��- V/ r \ 1 Closing PIu9 11111 r 0Ba"iii MINI .e Adapter(if used) OD = Shut Off Plug ID Opening Plug t/ Depth OD Baffle Adapter OD Bypass or Shut-off Baffle ® 1 ID By-Pass Plug Depth Shut-off Plug111 Float Collar It_ li Depth - By Pass Baffle OD Float Collar 0— Float Shoe j(T Depth IF Bypass Plug (if used) T Hole TD - Float Shoe "Reference Casing rinOD Sales Manual _ Section 5 Page 19 Version 1 May, 2015 i • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Compaiy 12.7 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use Jet Lube Seal or BOL 72733 thread compound. Dope pin end only w/paint brush. • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cmt returns to surface. 12.8 Install the Halliburton Type H ES-II Stage tool so that it is positioned at 2300' MD/2194' TVD. This should be approx. 450' TVD below the base of the permafrost. • Install centralizers over couplings on 5 joints below and above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. There are 6 holes, the tool is normally sent with only 4 pins installed. This will allow the tool to open at 3300 psi. 9-5/8" 40#L-80 TC-II Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 11,600 ft-lbs 13,600 ft-lbs Page 20 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Slze(O.D.): Weight(Wall): Grade: TC-II Casing 9-5/8 in 40.00 lb/ft(0.395 in) L-80 standard Material L-80 Grade liPir 80.000 Minimum Yield Strength (psi) 111111111111111111111111.1.113A 95.000 Minimum Ultimate Strength (psi) VAM USA Pipe Dimensions 4424 W.Sam Houston Pkwy.Suite 150 041 9.625 Nominal Pipe Body O.D. in Phone: 3-X 77-32 y ( ) Phone:713-479-3200 8.835 Nominal Pipe Body I.D.(in) Fax:713-479-3234 0.395 Nominal Wall Thickness (in) E-meal:VAMUSAsalesvem-use.com 40.00 Nominal Weight (lbs/ft) 38.97 Plain End Weight (lbs/ft) 11.454 Nominal Pipe Body Area (sq in) ✓ Pipe Body Performance Properties 916.000 Minimum Pipe Body Yield Strength (lbs) 3.090 Minimum Collapse Pressure (psi) 5.750 Minimum Internal Yield Pressure (psi) 5.300 Hydrostatic Test Pressure (psi) Connection Dimensions 10.235 Connection O.D. (in) 8.835 Connection I.D. (in) 8.750 Connection Drift Diameter (in) 5.23 Make-up Loss (in) Connection Performance Properties 916.000 (1) Joint Strength (lbs) 16.360 Reference String Length (ft) 1.4 Design Factor 916.000 Compression Rating (lbs) 3.090 Collapse Pressure Rating (psi) 5.750 Internal Pressure Rating (psi) 38.1 Maximum uniaxial bend rating [degrees/100 ft] Recommended Torque Values 11,600 (2) Minimum Final Torque (ft-lbs) 13.600 (2) Maximum Final Torque (ft-lbs) Page 21 Version 1 May, 2015 • • 1 ti Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 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. 12.12 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 12.13 Have emergency slips ready to go in the event we can not land the hanger. 12.14 R/U circulating equipment and circulate B/U. Reduce YP to <20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 12.15 After circulating, lower string and land hanger in wellhead again. Page 22 Version 1 May, 2015 N • Milne Point Unit L-46 Drilling Procedure Hilcorp Enna Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cmt operation. • Review test reports and ensure pump times are acceptable. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cmt pump or treating iron will not be pumped downhole. 13.4 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.5 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.6 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug). Mix and pump cmt per below recipe for the 1st stage. 13.8 Cement volume based on annular volume+ 30% open hole excess. Job will consist of lead& tail, TOC brought to stage tool. Estimated Total Cement Volume: Section: Calculation: Vol(BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (5585'- 2300') x .0558 bpf x 1.3 = 238.3 bbls 1338 ft3 annulus: Total LEAD: 238.3 bbls 1338 ft3 3fls,� 12-1/4" OH x 9-5/8" Casing (6585'- 5585') x .0558 bpf x 1.3 = 72.5 bbls 407.3 ft3 annulus: 9-5/8" Shoe track: 90 x .0758 bpf = 6.8 38.3 Total TAIL: 79.3 bbl 445 ft3 3S3 St- Page fPage 23 Version 1 May,2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Enerp Company Cement Slurry Design: Lead Slurry Tail Slurry System ArcticCEM TM System SwiftCEM TM System Density 10.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk - 1.16 ft3/sk Mixed 21.13 gal/sk 5.04 gal/sk Water 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. To operate the stage tool hydraulically,the plug must be bumped. 13.11 Displacement calculation: 6495' x .0758 bpf=278 bbls mud, 80 bbls water, 134 bbls mud The 80 bbls of water must be left across stage tool to ensure proper operation once opened. 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. / Page 24 Version 1 May, 2015 • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 13.14 If plug is not bumped consult with drilling engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 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. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface. Circulate until YP <20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cmt returns in the cellar or open the shaker bypass line to the cuttings tank. Have sacks of sugar available and vac trucks ready to assist. Ensure to flush out any rig components used to route cmt. Page 25 Version 1 May, 2015 • • 14 Milne Point Unit L-46 Drilling Procedure Hilcorp Ewa�v�r Second Stage: 13.18 Prepare for the 2nd stage as necessary. Hold another pre job meeting if crew change has occurred. 13.19 Load ES cementer closing plug in cmt head. 13.20 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 13.21 Pump remaining 55 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume+200% open hole excess. Job will consist of lead & tail, TOC brought to surface. However cmt will continue to be pumped until clean spacer is observed at surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 20" Conductor x 9-5/8" (110')x .27 bpf x 1 = 29.7 bbls 167 ft3 casing annulus: 12-1/4" OH x 9-5/8" Casing (1800'- 110') x .0558 bpf x 3 = 283 bbls 1589 ft3 annulus: Total LEAD: 312.7 bbls 1756 ft3 u$ - 12-1/4" OH x 9-5/8" Casing (2300'- 1800')x .0558 bpf x 2 = 56 314 ft3 annulus: Total TAIL: 56 bbls 314 ft3 a 70 k 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement Calc th 2300' x .0722 b = 166 bbls mud Page 26 Version 1 May, 2015 • Milne Point Unit L-46 Drilling Procedure Hilcorp Enemy comp./ 13.27 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. 13.28 Decide ahead of time what will be done with cmt returns once they are at surface. We should get back approx. 150 bbls of cmt slurry. 13.29 Land closing plug on stage collar and pressure up to 1000— 1500 psi to ensure stage tool closes , Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Back out and L/D landing joint. Flush out wellhead with FW. 13.30 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. 13.31 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 a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping ofjob. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. 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 and cdinger@hilcorp.com This will be included with the EOW documentation that goes to the AOGCC. Page 27 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Elmo,Cmnp.nY 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard tubing spool. Install pack-off 9-5/8" P-seals. Test to 3000 psi. 14.3 N/U 11" x 5M BOP as follows: • BOP configuration from Top down: 11"x 5M Hydril annular BOP/11"x 5M Shaffer double ram/11"x 5M mud cross/11" x 5M Hydril 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 (1) manual valve & (1) HCR valve on kill side of mud cross. (manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 5" BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. 1C • 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 8.9 ppg Baradrill-N fluid for production hole. 14.8 Set 10" ID wearbushing in wellhead. 14.9 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.10 Install 5" liners in mud pumps. Page 28 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. • 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. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 5" 19.5# S-135. • Run a ported float in the surface hole section. 15.2 8-1/2"BHA(Includes GR+Res+ADR LWD components & PWD): Page 29 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company COMPONENT DATA ItemOD ID Gauge Weight Top Length Cumulative # Description ' Arial Number s, (n) (in) (in) l,lbpbConnection (ft Length (ft) E. HOBS-FX650 4 400 2.500 8.500 172-13 P 4-12'REG 1.00 1.00 ® 7"SperryDrill Lobe 7/8-6.0 stg 7.000 '"® 93.13 �' - Stabilizer -__ 7.750 _-- ® Non Mag Float Sub 6.750 2.750 101 71 B 4-1/2"IF 3.00 31.38 © Integral Blade Stabilizer(NM) 6.750 2.813 8.375 100.77 B 4-112"IF 5.00 © 6 314"DM(Directional) 6.750 3.125 103.40 B 4-112"IF 9.20 45.58 Kill 6 3/4"DGR(Gamma) 6.750 1.920 97.80 B 4-1/2"IF 4.55 50.14 NM 6 314'EWR-P4 (Resistivity) 6.750 2.000 104.30 84-1/2"IF 12.10 62.24 E. 6 314'HCIM (Processor) 6.750 1.920 _ 101.70 B 4-112"IF 4.97 67.21 © 6 314"ALD Collar 175C 30KSI 6.750 1.920 8.250 104.30 P NC 50 14.54 81.75 _ Stabilizer -__ 8.250 _--� 10 6 314"CTN Collar 175C 30KSI 6.750 1.905 102.30 B NC 50 11.84 93.59 m 63/4"TM-HOC(Pulsar) 6.900 3.250 103.60 8 4-112"IF 15.59 109.18 ® 6-314'Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-112"IF 30.00 139.18 ® 6-3/4"Non Mag Flex Drill Collar 6.750 2.813 100,77 B 4-112"IF 30.00 169.18 El X-0 4-112"CDS 40 Box X 4-112"IF Pin 6.500 2.750 92.85 B 4.5"CDS 40 2.75 171 93 ® 6 Joints 4-112"CDS 40 HWDP - 4.500 2.500 37.47 180.00 En X-O 4-1/2"IF Box X 4-1/2"CDS 40 Pin 6.500 2.750 92.85 B 4-1/2"IF 2.75 354.68 ME Weatherford 6-1/4"Jars 6.250 2.250 91 01 KnISMI 30.00 384.68 MEI X-0 4-1/2"IF Pin X 4-t/2"CDS 40 Box 6.500 2.750 92.85 B 4.5"CDS 40 2.75 387.43 19 19 Joints 4-1/2"CDS 40 HWDP 4.500 2.500 37.47 570.00 957.43 „,..�..i0:'''<: 957 43 BIT DATA -... Bit Number Nozzles : 5x13 Bit Size (in) : 8.500 TFA (in2) : 0.6481 Manufacturer Dull Grade In . Model Dull Grade Out .• Serial Number . 15.3 Primary Bit: Page 30 Version 1 May, 2015 • • 11 Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 8-1/2" (216mm) SFE5fi PRODUCT SPECIFICATIONS Cutter Type X2-Tough Drilling IADC Code S424ho Body Type STEELy, Total Cutter Count 29 +� 1*r Cutter Distribution il.ntm 19mm r * Face 0 19 r 7 it Gauge 10 0 Number of Large Nozzles 5 i, Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 0 Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 1' Junk Slot Area(sq in) 20.81 t ' PIP , Normalized Face Volume 73.86% .5 API Connection 4-1/2I.F.PIN 4100I Recommended Make-Up Torques 23,743 FNlbs. Nominal Dimensions" Make-Up Face to Nose 8.31 in-211 mm i Gauge Length 3 in-76 mm r Sleeve Length 0 in-0 mm Shank Diameter 6.688 in-170 mm Break Out Plate(Mat.(t/Legacy#) 181960/44073 Approximate Shipping Weight I 20Lbs.-54Kg. SPECIAL FEATURES Anti-Balling Coating,Short Shank,EDL Tool Specific Gage,.084"Dia Step,.126"Dia Step Material#761417 15.4 8-1/2"hole section mud program summary: Page 31 Version 1 May, 2015 • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum(N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco 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. System Type: 8.9—9.2 ppg Baradrill-N drilling fluid Properties: Depths Density Plastic Viscosity Yield Point Chlorides API FL pH System Formulation: Baradrill-N Product Concentration/Function Water Base Fluid Busan 1060 0.4 ppb Biocide Soda Ash 0.25 ppb PH/Hardness Control Flowzan 1.0 ppb Viscosifier/Rheology KCL 21.8 ppb weight/inhibition NaCI Salt 20.0ppb weight/inhibition Poly Pac Sup UL 0.75 ppb API Fluid Loss EMI-2009 2-3%v/v Clay/Shale inhibitor Safe-Carb 40 If needed for weight increase over Conqor 404 9.0ppg Asphasol Supreme Corrosion Mitigation Sack Black 4ppb Shale/Coal Stabilizer 3ppb-Gilsonite Shale/Coal Stabilizer Page 32 Version 1 May, 2015 • • Milne Point Unit L-46 111 Drilling Procedure Hilcorp Energy Company 15.5 TIH w/ 8-1/2" directional assy to stage tool. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. Drill out stage tool as follows: • Do not exceed 75 rev/min rotation speed. A good range is 40 to 75 rpm. • Because of aggressive nature of PDC bits, drilling with minimal WOB is recommended. Approx 2-5 k is enough. • Apply weight and allow it to drill off before applying more. • After drilling out, chase any remaining debris to bottom with the drill bit. 15.6 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.7 R/U and test casing to 3500 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 6870/2 =—3500 psi 15.8 Drill out shoe track and 20' of new formation. 15.9 CBU and condition mud for FIT. 15.10 Conduct FIT to 12 ppg EMW. 15.11 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • Pump at 500 - 550 gpm. • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Pump water or other low vis sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1500—2000 ft if necessary. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Ideally, we would like to stay in section 100% of the time and DO NOT want to serpentine between the upper and lower lobes. 15.12 Open hole sidetracking practice: • If a known fault is coming up, put a slight"kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 33 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcor ' Energy Con 15.13 At TD; pump low vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the 9-5/8" shoe. If backreaming is necessary: • Circulate at full drill rate (500—550 gpm). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe and circ at least a b/u once at the shoe. 15.14 TOH with the drilling assy, stand back BHA if possible. Rabbit DP on TOH. 15.15 No open hole logs are planned for the production hole section. 16.0 Run 5-1/2" Production Liner 16.1. Install and test 5-1/2" casing ram in top ram cavity. Test to 250/3000 psi. 16.2. Test VBRs on 2-7/8"test joint to 250/3000 psi. 16.3. Re-install wear bushing in wellhead after test. 16.4. R/U 5-1/2" casing running equipment. • Ensure 5-1/2"DWC/C x DS-50 crossover is on rig floor and M/U to FOSV. • 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. 16.5. Run 5-1/2" slotted production liner. • Use "Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install swell packers as per guidance from Operations Engineer. • Ensure all plastic packing is removed from element. • Do not place tongs or slips on element. • Run packoff and float shoe on bottom. 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 9,800 ft-lbs 11,000 ft-lbs 14,800 ft-lbs 1 Page 34 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight (Wall): Grade: DWC/C-HT Casing 5-1/2 in 17.00 lb/ft(0.304 in) L-80 standard wog Material L-80 Grade 80.000 Minimum Yield Strength (psi) IIIMENNIMPUSA 95.000 Minimum Ultimate Strength(psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 5.500 Nominal Pipe Body O.D. (in) Fax:713-4794234 4.892 Nominal Pipe Body I.D.(in) E-ma31:VAMUSAsalesvam-usa.com 0.304 Nominal Wail Thickness (in) 17.00 Nominal Weight (lbs/ft) 16.89 Plain End Weight(lbs/ft) 4.962 Nominal Pipe Body Area (sq in) • Pipe Body Performance Properties »M� 397,000 Minimum Pipe Body Yield Strength (lbs) 6,290 Minimum Collapse Pressure(psi) 7.740 Minimum Internal Yield Pressure(psi) ,., 7.100 Hydrostatic Test Pressure (psi) a„ Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection 1.D.(in) 4.767 Connection Drift Diameter(in) 4.13 Make-up Loss(in) 4.962 Critical Area(sq in) ) 100.0 Joint Efficiency(%) zn .,E Connection Performance Properties 397,000 Joint Strength (lbs) 16.680 Reference String Length(ft) 1.4 Design Factor 428.000 API Joint Strength (ibs) 397.000 Compression Rating(lbs) 6.290 API Collapse Pressure Rating (psi) 7,740 API Internal Pressure Resistance (psi) 66.7 Maximum Uniaxial Bend Rating[degreesr100 ft] Appoximated Field End Torque Values 9.800 Minimum Final Torque (ft-lbs) 11,000 Maximum Final Torque (ft-lbs) 14.800 Connection Yield Torque(ft-lbs) Page 35 Version 1 May, 2015 i Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 16.6. Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 16.7. 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. 16.8. If inner string is to be run, R/U false rotary and run inner string at this time. 16.9. 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. 16.10. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. 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. 16.12. DP should autofill. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth+ S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 16.15. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.16. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.18. Rig up to pump down the work string with the rig pumps. 16.19. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.20. Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 min each up to 4000 psi. Page 36 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 16.21. Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. Bleed off pressure and pickup to verify that the HRD setting tool has released. If packer did not test, rotating dob sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. P/U above liner top packer and displace well to 8.9 ppg completion fluid. 16.24. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 16.25. RIH w/remaining DP out of derrick and L/D same. 17.0 Run 7-5/8" Tieback 17.1 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install and test 7-5/8" casing rams in top ram. v 17.2 R/U 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 17.3 P/U tieback seal assy and set in rotary. 17.4 M/U first joint of 7-5/8"to seal assy. 17.5 Run 7-5/8"tieback to position seal assy two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. • Install ported collar so it is positioned at 2500' MD when landed out. 17.6 M/U 7-5/8" SLID-II to DP crossover. 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. 17.9 Note seal assy entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. Page 37 Version 1 May,2015 S Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 17.10 Continue lowering string and land out on no-go. Set down 5 — 10k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & stand back DP stand, L/D XO. 17.12 M/U (or L/D) necessary joints and pup joints to position seal assy 1 ft above"NO-GO DEPTH" when tie-back hanger lands out in wellhead. 17.13 P/U hanger assy. Top of hanger landing joint is 7-5/8" SLIJ-II. Ensure crossover is available to allow circulation down the string. 17.14 R/U to circulate down tieback. Displace 7-5/8" x 9-5/8" annulus to inhibited packer fluid. 17.15 Confirm hanger has seated properly in wellhead. Should be approx. 13k lb on hanger when landed. Make note of actual weight on hanger on morning rpt. 17.16 Run in hanger lock downs. 17.17 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. Test void to 3000 psi/ 10 min. 17.18 R/D casing running tools. 17.19 Run in hole with 2-7/8"tubing and ported collar opening tool. Shift open ported collar at 2500'. Circ diesel freeze protection from 2500' to surface in 7-5/8"x 9-5/8" annulus. 17.20 Close ported collar. 17.21 Test 7-5/8" x 9-5/8"production annulus to 1000 psi/ 30 min. Nt 17.2 POH and stand back 2-7/8"tubing for ESP run. 18.0 Run ESP assy. 18.1 M/U ESP assy and RIH to setting depth. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. 18.2 Land hanger, RILDs and test hanger. 18.3 Install BPV and N/D BOP. 18.4 N/U tree adapter and test tree. Pull BPV. Page 38 Version 1 May, 2015 Milne Point Unit L-46 Drilling Procedure Hilcorp Enemy Company 18.5 Circulate diesel freeze protection down 2-7/8"x 7-5/8" annulus (Volume should equal capacity of tubing to 2500' +tubing annulus to 2500'). Connect IA to tree and allow diesel freeze protect to "U-tube" into position. 18.6 Shut in well and prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.0 RDMO 19.1 RDMO Nordic #3. Page 39 Version 1 May,2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 20.0 Diverter Schematic a16" Full Opening Knife Valve , jappilim I I,I Schaffer 21-114"2M Annular I.IIB LI 1.1 I.I 111 1.I 0-IIIIII ., n 21-1/4" 2M---------. Diverter "T" 2.9981 a III - M 1 7. g _ - _ - 111 Is III III III I,I 21-114" 2M 16" Diverter Line—/1 Spacer Spool 4.0380 Ground Level ® SBM ® ® 16-3/4" 3M x 21-114" 2M DSA I -a) 4iik IN, Seaboard Casinghead, S-22-AP-8� 16" SOW x 16-3/4" 3M; (2) ea 2-1/16" 5M studded outlets 20" Casing CG.J` ° Page 40 Version 1 May, 2015 0 0 Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 21.0 BOP Schematic / 1 \ I t 6 0 Hydril Annular BOP 11"x5M Lailla71.11111a., ..r.. —ler i0`43/�- DQ Shaffer 11" x SM 0 ii _ vZ p.0 0 X1=-1 memom a a o 0 o E I1—I epi " °O naa MI Aft III /,--3`x 5M HCR II tarok • Kill Line I in 1[ II Fe no Il`~::~ ll IN l —Choke Line �3"x 5M Manual Gate Valve -�.el Yyd "1—� Hydril 11"x 5M - ® 4 1I- 1 V() • A , Y NNIMINIM w -.----`—'--11"x 5M -I— —I- _I ft s % l 9-5/8"DBL D Seal I_ „'1(M. up El 2-1/16"x 5M Casing Hanger L�•r��a i a 16-3/4"x 3M SMB-22 -'j` j�i��'AO 16-314"NOM I 1 9-5/8"BTC Btm x 2-1/16"x 5M 10.5"-4 SA Pin Top W/Primary Sea 20"Casing 9-5/8"Casing Page 41 Version 1 May, 2015 • 0 II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 22.0 Wellhead Schematic I HILCORP ALASKA i SCHRADER BLUFF WELLS HO-35449H ifr i 2-9/16 SM i" ' '. 1 H01.D-0OWN FLANGE ADAPTER. ESP-2CL ll TOADSTOOL — 11 X 7-9/16 51,0 _ .SII I■I ' 11 9.1 • TUBING HANGER S-80-ESP INI 1 al '■I 11 x 2-7/8 810 TOP X . _c ! ��. i API MOD BTM EST 94.5 F/tAURUS PENS TRATCR■7 =�1 !I•i A•`' r. 43-217-00 M41 � MR 1 �. •1\� �`i 11 :N 1 V `2-I/15 5M CASING HANGER. SMB-22 -,• ,.' — 11 X 7-5/8�--. I _ �, W/PRIMARY SEAL p EST : IMO IMO26.0 i _ i IA • 9..5/8 DBL U awl inl I 2-1/16 5M MI I' i ill CASING HANGER SNB-22 _--_-- 16 X 9-5/8 : ‘111",,,.._. w/PRAIARY SEAL o = 26.8 ]1• `•�: EST �� i� { iu `� �.� '� /__. 1 z to el• 13-3/8 CASING 9-5/8 WEIRI 7-5/8 CASING--. ._i OIL 8 GAS. 6,000 P9 ESP WELLHEAD ASSEMBLY ONFMSIONS SHOWN CN THS ORANING ARE 2-7/B CASING�.-q 9-11E BACK STYLE/ ESTMATES(4 Y ANO CAN VARY S(iW N4TLr "- T3-3/!X 9-S/8 x 7-3/8 x 2-7/8 OCPENQWYG ON RAW MATERIM LENGTHS. RESTRICTED CONFIOFN A. DOCS MINT _15-- ` � .....r..�r.>.r.. RPL 19 119JUNi5 . .-, v pMENSIONS WAN 5110110 OF CENSURED .; 114„,9, ,."" r� 000100 au FOR REFERENCE PLRPOSES CAT. r..S5, ...g.0=="" rem 4D-000619 Page 42 Version 1 May, 2015 0 0 Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 23.0 Days Vs Depth Days Vs Depth 0 1 , .5thrader Bluff Well MPI-19(2004} . ----Mpi-is poll) \.\\ —MPI-1712004) 20030 \ -MPI-1512002) r )11 4030 lilk' Ili 6030 - _ !1 t i 8 7 iv 111 8030 I 10000 12000 14000 i 0 5 10 15 20 25 30 Days Page 43 Version 1 May,2015 • 0 11 Milne Point Unit L-46 Drilling Procedure Hilco p Energy Company 24.0 Formation Tops Formation TVD (Top) TVD (Bottom) Anticipated Pressure (Psi) SV1 2175 3545 973 Ugnu LA1 3521 3748 1575 Ugnu MB 3749 3998 1677 SB NB Sand Top 3999 4135 1788 SB OA Sand Top 4136 4147 1853 7 Page 44 Version 1 May, 2015 • S Milne Point Unit L-46 Drilling Procedure Hilcorp Emily Company 25.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0—2.0 ppb DRILTREAT to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti-Collison: There are a number of wells in the vicinity of L-46. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations btwn surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on `L"pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. Page 45 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Emu Company 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore,pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 500 gpm.• Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a"ramp" in the wellbore to aid in kicking off(low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on `L"pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on"L"pad. Page 46 Version 1 May, 2015 • • Milne Point Unit L-46 II Drilling Procedure Hilcorp Energy Company 26.0 Nordic #3 Rig Layout (Drillers Side) Cl 104 I a li ; © w ,Co - Calis�ta lista pr RIG NO. 3 Ti..Dons,owlud.g aprofa•ream&m .o and 2h.r coma,/ 97hr de.:p�nr. 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ACCEPT FLOW UES 10'C Well End r 2 VT' `v-M I u r „-r— I n ,o, p I I I I I I j I id ,.,..... i -ir : , a Ew (i.L..... .... 'r �t l!t F MCA � 4 s a tf . 34)bp. otaitc arras WA XII TAI.1 Covalaitult PPE 0001 1E111 LI111 1 u F""shin' u I 1 11111111111 TOP VIEW Page 48 Version 1 May,2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 28.0 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. 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Page 50 Version 1 May, 2015 • • II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 30.0 Casing Design Information Calculation & Casing Design Factors DATE: 5/14/2015 WELL: MPU L-46 DESIGN BY:Luke Keller Design Criteria: Hole Size 12-1/4" Mud Density: 9.5 ppg Hole Size 8-112" Mud Density: 9.5 ppq Hole Size Mud Density: Drilling Mode MASP: 1439 psi(see attached MASP determination &calculation) MASP: Production Mode MASP: 1439 psi (see attached MASP determination &calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.494 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD ` 9-5/8" 5-1/2" 7-518" Top(MD) 0 6,385 0 Top(TVD) 0 4,147 0 Bottom(MD) 6,585 13.200 6,385 Bottom(TVD) 4,147 4,147 4,147 Length 6,585 9,053 6,385 Weight(ppf) 40 17 29.7 Grade L-80 L-80 L-80 Connection TC-II DWC/C HT SLIJ II Weight w/o Bouyancy Factor(lbs) 263,400 153,901 189.635 Tension at Top of Section (lbs) 1-263,400 153,901 189,635 Min strength Tension (1000 lbs) r 916 347 683 Worst Case Safety Factor(Tension) 3.48 2.25 3.80 Collapse Pressure at bottom (Psi) 2,049 2,049 2,049 Collapse Resistance w/o tension(Psi) 3.090 7,100 4,790 Worst Case Safety Factor(Collapse) 1.51 3.47 2.34 MASP(psi) 1.439 1,439 1,439 Minimum Yield(psi) 5.750 7,740 6,890 Worst case safety factor(Burst) 4.00 5.38 4.79 Page 51 Version 1 May, 2015 • • Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 31.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Flole Section }1 ilcorp MPU L-46 Milne Point Unit MD TVD Planned Top: 6585 4147 Planned TD: 13200 4147 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,147 1855 Oil/Wet 8.6 0.447 Offset Well Mud Densities Well MW range Top(TVD) Bottom(ND) Date L-37(1998) 8.9-9.3 Surface 7,050 1998 L-35(1997) 8.4-9.2 Surface 5,687 1997 L-34i(1997) 8.4-9.4 Surface 5,842 1997 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 4147(ft)x 0.78(psi/ft)= 3235 psi 3235(psi)-[0.1(psi/ft)*4147(ft)]= 2821 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4147(ft)x 0.447(psi/ft)= 1853 psi 1853(psi)-0.1(psi/ft)*4147(ft) 1439 psi ' Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 52 Version 1 May, 2015 0 0 11 Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 32.0 Spider Plot (NAD 27) (Governmental Sections) :::`♦♦ vt , f Ji Pr, r 1, 'r rTi / r rr �,N i' '♦ • �`\!``\rA 1 r r +, ! r ' ' r . / s w�a A ,d/,,�r �+`.- r E r r + r rr r / • •Z Vs ,!i i Sec.6 ♦_ •\r 1 r+ ' r Sec.5/ CO- Sec.4 ;%. .1' {625} '♦♦ t �� 11 rr r / �r C09 -F:F F r a I ' I // ' ,' ' / \ r.= 11 t 4 + M / // '' ' • ♦.♦ ti1} y �+ r I� �'/ __ • ' ♦ ♦♦ ' tM I .' . / d , ▪ 1 �` .`♦ ',AQL025509//r ,' ADL047434 • ,` 1 .,. 'wFe �" r MPL-46 SHL' Li, Sec-7µ ' , 'q--''', /' fr f• a Sec.9 (628) ', i r -.%,, LSA - - Y _, rrr./�j/ ��/'' •/•I it `` ,` 3. _ _ - ' _ f ',� i ./ 'rl .1, R,w - - ' • i, //I. �. ' �.UO13N01OE� MPL-46 TPH `4. • -_ - f e1 EE_„,, / / ♦♦ // Sec- 18 Sec.17 ♦� Sec 16 / r630) ‘:S'. MPL-46 BHL • Legend ADL315848 • MPL-46 SHL X MPL-46 TPH J.,. MPL-46 BHL • ' r Other Surface Holes(SHL) r, Sec.20 ) `, ,,,.`Sec.21 • Other Bottom Holes(BHL) m • atIn - - - - Other Well Paths ft X ' I 1 +i ♦ < 1 .A'a i3-t�ll7 etr • �• .♦ .'r+= 1 hoar•, t Page 53 Version 1 May,2015 • •• Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 33.0 Surface Plat (As Built) (NAD 27) , 31 I 32 I 33 I ,,,./b1 1 I ]6 I 4145' Hill I 1 No 1 1 f "' �i 1 s 1 4 I \ \ 1 / -I`�_ -1 - 1- \ \ I , 32 ■ 33 i _','C V 4.'"L-PAD i' t i r I \i I 24 • 29 -N_• :2 f 1 6 4 1 "',rte' 1 ,1/ 20 ■ 21 • 1 - THS PM�OJECT ( 1 i / 45 ■ ` ----1 ,.. 13, 16 11 1 --+ -- • , 3 z4 rr- ,9 I m 1 r 39 ■ • 42 VICINITY MAP 1 _ 1 !LT/ I 1 ■ • 9 34 ■ ■ 14 3 • • 10 . 15 ■ ■ 47 2 • 7L-49 `,1OVA1111f��OF 4 11 6 35436 537 1150 `` �, {ypg :?*..- 1a .1,.A,91t �. t / j.:• _ y I. , ;.Ri"<,rd F. Allison I '.. „,-.,... 10608 • \ 1 hlr#/t t ttKW&t `.avp 1 I I SURVEYOR'S CERTIFICATE, NOTES; LEGEND I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED MD UCENSED 1. ALASKA STATE PLANE COORDINATES ARE 4- AS-BUILT CONDUCTOR TO PRACTICE LAND SUR'.EYING IN ZONE 4,NA027. ■ EXISTING CONDUCTOR THE STATE OF ALASKA MD THAT 2. BASIS OF LOCATION IS L-PAD MONUMENTS THIS AS-BUILT REPRESENTS A SURVEY L-1 NORTH MD L-2 SOUTHMADE BY ME OR UNDER MY DIRECT AND THAT ALL 3. ELEVATION DATUM IS MSL. SUPERVISION EHSICNAND OTHER DETAILS ARE 4. 0E00E1,C POSITIONS ARE NAD27. GRAPHIC SCALE CORRECT AS OF JULY 4, 2015. 5. PAD MEM SCALE FACTOR PS: 0.9999023 0 100 203 400 6. DATE OF SURVEY_ JULY 4, 2015. T I 7. REFERENCE HELD BOOK: HC15-02 PGS. ( IN FEET ) 50-06 1 Inch -200 ft LOCATED WITHIN PROTRACTED SEC. 8, T. 13 N., R. 10 E., UMIAT MERIDIAN, AK. WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POStTION(D.DD)BOX ELEV. OFFSETS Y=6,031,494.52 N= 1110.03 70'29'48.865" 70.4969071' 3,303'FSL L-46 X= 545.148.08 E. 1422.61 149'37'50.919' 149.6308099' 17.5' 4,733'FEL Y=6,031,478.37 N. 1110.21 70'29'48.710` 70.4968639' 3,287'FSL L-48 X= 543,122.81 E= 1392.18 149'37'51,681" 149.6310225' 17.5' 4,759'FEL Y=6,031,591.23 N= 1179.23 70'29'48.665" 70.4971930' 3,408'FSL L-49 X= 54.5.185.00 E=' 1509.82 149'37'50.916" 149.6304998' 17'0' 4.695'FEL mei Kum_VMS 44130135_ II lIHikorp Alaska ____. _ Fill u„--- auomo 7/slaa,d g1R4..P1___ ate.0lik scut MPU L-PAD AS-BUILT CONDUCTOR t$1,1,150/41 MO Nw•roNrAINI a r 1'.200' WELLS L-46, L-48, L-49 I a 1 .n ax sv12. 4n.au Page 54 Version 1 May,2015 • S Milne Point Unit L-46 Drilling Procedure Hilcorp Enasy Comps"), 34.0 Offset MW vs TVD Chart MW vs TVD Offsets 0 L-37 L-35 1000 �--L-34i 2000 3000 — — 0 4000 41614111\) 5000 6000 7000 8000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud Weight{PM) Page 55 Version 1 May,2015 • • II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company 35.0 Drill Pipe Information 5" 19.5# S-135 DS-50 Drill Pipe Configuration <,t Pipe Body OD i nr 5.000 80%Inspection Class t Pipe Body Wall Thickness nn)0.362 Nominal Weight Designation 19.50 i Pipe Body Grade S-135 Drill Pipe Approximate Length 31 5 1 Drill Pipe Length Rangel 1SmoothEdge Height :13/32 Raised Connection GPDS50 Tool Joint SMYS c 120,000Tool Joint OD 6.625Upset TypeIEU Tool Joint ID n.3.250 (Max Upset OD (DTE) 5.125Pin Tongg1Friction Factor �1 Box Tong .__ n;�1 2 Nalc tar`.g rotate-ray Include hlto!]clnp. Drill Pipe Performance Drill-Pipe Length Rangel Performance of Drill Pine with Pipe Body at Best Estimates Nominal 1 50%Inspection Class "Mi' IC atr i .w to Coating. (leas-..accurate; hooted reakein Operational Max Tension Drill Pipe Adjusted Weight hbz-ni 24.11 23.29 Torque 111 asP Torque in-Iasi opo Fluid Displacement ;"Ili 0.37 0.36 Maximumad(J*43,100 Tension Only 0 560,800 Fluid Displacement 0Bbl:n,0 0088 0.0085 cpmar'°�oaduq 39,600 Tension Only p 410.500 Fluid Capacity (92,1,40.1'1 0.70 0.72 Fluid Capacity Banti i 0.0169 0.0167 0.0172 36,100 560,800 3.125 Wm.,.Mur 0urretned Lo 1Q 32.100 467.400 Drift Size (m Note ON field barrel equals 42 US gallons. Note 0'I ppe assembly valor are nest estimates and may vary due to tale body noir Lolerance,internal plastic coatingand other rxk*s. Connection Performance GPDS50 ( 6.625(w,) OD X 3.250 iv)) ID ) 120,000 (psi) Appdetl Myo.+-up Teriswn al 5noutter Tension at Connection Tool Joint Dimensions TorqueSeoaratgn Yell n-eo) n ni ril Balanced 00 gni 6.435 Maximum Make up Torque 43,100 Tensile Limited 1,046.900 Minimum Tool Jowl 00 for API 5.930 Minimum Make-up Torque 36,100 1.202,500 1.250.000 PrQmiumCMss ri0" --_-- - Note The rate,, t me akup axone should be applied Allen nossib e - Minimum Tod Joint 00 for 5.93 i. Note To niael'n,ze connection,operational!ensile.a MUT IT4,ii 371(0 nabs;.shout]no apti e= COW11erbOre Gni Tool Joint Torsional Strength to test 71.800 Tool Joint Tensile Strength (flat 1,250,000 Elevator Shoulder Information Elevator OD 3132 Raised 6.812 tnj 17 SmoothEdge Height Nominal Tool Joint Worn to Bevel Worn to Min TJ OD for 13/32 Raised OD Diameter API Premium Class Box OD h.:6.812 6.625 6.063 5.930 Elevator Capacity lbs:1,658,000 1.440,200 823.600 685.600 `' """"""'"'""`"'"""' Note Elevator capacity based :e assn d Elevator Bore.no wear ractci and contact stress or t'o.10Cps1. - Assumed Elevator Bore Diameter ,n 1 "" 5.219 1 Note A raised eevator 00 Increase:elver:.cagac a w-th[.,t affecting crake-op torque. Pipe Body Slip Crushing Capacity Pipe Body Configuration( 5(N) OD 0.382 int Wall S-135) Nominal 80%Inspection Class API Premium Class 177 Slip Crushing Capacity (Ds)498.300 396.500 396.500 Note:Pip Crushing 514 mating toad is caiciraleo wan Te Sp'Fencctd etra.Vilor to-.n Why Coes.Oral Ppe Assumed Slip Length deo 16.5 F04 in de slip Arca'v vk*co,1509 ss reap lanai'and aanwerc tad rade,snow and is for refe+ence Transverse Load Factor 11() 4.2 only Upmanna aPepe deni whe sip design ana rootlike coellclenla('01.0,kddr°`OM1210a tore in sipsare Me DO and MI Iodation..aa other dads carnal 011 the Tag mYuraClxr Tx midland rrvrtatnn. Pipe Body Performance Pipe Body Configuration( 5 tint OD 0.382 aro Wall S-135) Nominal 80%Inspection Class API Premium Class Pipe Tensile Strength ami 712,100 560,800 560.800 Pipe Torsional Strength :l" 74,100 58.100 58.100 TJIPipeBody Torsional Ratio 0.97 1.24 124 80%Pipe Torsional Strength whist 59.300 _ 46.500 46.500 Burst 1ple 17.105 15.638 15,638 Nola:Nvrinat Burs: • Calla se saes pascuwled a1 tsrsa xew I' ; i P 15.672 10.029 10,029 err APi. l Pipe OD tau�5.000 4.855 4.855 Wall Thickness lot 0.362 _0.290 0.290 Nominal Pipe ID 1aa>,4276 4.276 4276 Cross Sectional Area of Pipe Body for 2l 5.275 4.154 4.154 Cross Sectional Area of OD ctrl^n 19.635 ^18.514 '18.514 Cross Sectional Area of ID (ln^; 14.360 14.360 14.360 Section Modulus tla^31 5.708 4.476 4.476 Wry Polar Section Modulus ,in"3l 11.415 8.953 8.953 Grant Page 56 Version 1 May, 2015 ! • II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company Operational Limits of Drill Pipe Connection GPDS50 Tool Joint OD ;,,,;16.625 Tool Joint ID „n 13250 Tool Jowitt Specified Minimum 120,000 Yield Strength (PO, Pipe Body I 80%Inspection Class Pipe Body OD ,, 5 Wall Thickness ,,„10.362 Pipe Body Grade I5-135 Combined Loading for Drill Pipe at Combined Loading for Drill Pipe at AMaximum Make-up Torque= 43.100 in-b.) Minimum Make-up Torque= 36,100 in-ib.. Operational Assembly Pipe Body Connection Mos Operation Assembly Pipe Body Coanecnnn IFTorque Max Tension Max Tension Tension I Torque Max Tension mi.ter.ion Max Tension ' ,n-1^5) :ins, {los, 'm o,1 i1-lbs ,lbs) tabs Ons, 0 560,800 560.800 1.046.900 0 560,800 560.800 1.202,500 2,100 560,400 560,400 1.046.900 1.700 560,500 560.500 1.202,500 4,200 559.300 559,300 1.046.900 3.400 559.800 559.800 1.202.500 6,300 557,500 557,500 1.046.900 ' 5.100 558.600 558.600 1,202,500 8,300 555.000 555,000 1.046.900 6.800 556,900 556.900 1.202,500 10,400 551,700 551,700 1.046.900 ' 8.400 554.900 554.900 1,202.500 12,500 547,600 547,600 1.046.900 10.100 552.200 552.200 1.202.500 ' 14,600 542.800 542,800 1.046'.900 11.800' 549.100 549.100 1.202.500 16.700 537.100 537,100 1.046.900 13.500 545.400 545.400 1.202,500 18.800 530,600 530.600 1.046.900 ' 15.200 541,200 541.200 1.202,500 20,800 523.600 523.600 1.046.900 16.900 536.500 536.500 1202.50 22,900 515,400 515,400 1.046.900 . 18.600 531,300 531.300 1.202,500 25.000 506.200 506,200 1.046.900 20.300 .525.400 525.400 1.202,500 27,100 496.100 496.100 1.046.900 22,000 519,000 519.000 1.202.500 29,200 484.800 484.800 1,046.900 23.700 512.000 512.000 1202.500 31,300 472,500 472,500 1,046.900 25.300 504.800 504,800 1.202.500 33.300 459.600 459,600 1.046.900 27.000 496.600 496.600 1.202.500 35,400 444.700 444,700 1,046.900 28.700 487.600 487.600 1,202.500 37.500 428.400 428.400 1.046.900 ' 30.400 477.900 477.900 1202.500 IVI 39,600 410.500 410.500 1.046.900 32.100 467,400 467.400 1.202.500 Operational drilling torque is limited by the Make-up Torque. Operational drilling torque is limited by the Make-up Torque. Connection Make-up Torque Range Make-up Torque Connection Max ,.,-n„Tension ,r,, Min MUT 36.100 1,202,500 36.900 1,229,200 37.700 1,243,600 38.400 1,218,100 39.200 1,189,000 40.000 1,159,800 40.800 1,130,700 41.500 1,105,200 42,300 1,076,100 Max MUT 43,100 1,046,900 Page 57 Version 1 May,2015 • • II Milne Point Unit L-46 Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection GPDS50 = Tool Joint 00 ,,, 6.625 Tool joint ID ,,,. 3.250 Tool Jc+nl Specified M nirnum 120.000 Yield Strenglh Ip,lt Connection Wear -- Tool Connection Max Con>recho,Max Min MUT Connection Max Joint 00 Torsional MUT Tensic," Tension New OD Strength g •'1 -.i .^,.;b. :Ibsi 11-lbsi In= 6.625 71,800 43,100 1,046,900 35,900 1.195.900 6.562 ,71,800 43,100 1,034,900 35.900 1.208.700 6.499 71,800 43,100 1,022,600 35,900 1,222.400 6.435 71,800 43.100 1,009,800 35.900 1.237.500 It 6.372 71,200 42,700 1,008,100 35,600 1.245,200 6.309 68.000 40,800 1,057,300 34.000 1.207.700 6.246 64,800 38,900 1,104,800 32,400 1.169.800 1 6.183 61,700 37.000 1,150,400 30,800 1.131.300 6.f2 58,600 ' 35,200 1,190,900 29.3x0 1,096,100 = -- - 6.056 55,500 33.300 1,232,300 27.800 1.060.800 1Nons CID 5.993 52,600 31,500 1,227,200 26.300 1.024.600 5.93 49,600 29,800 1,187,100 24.800 '987.900 Pipe Body Combined Loading Table(Torque-Tension) Pipe Body 80%Inspection Class Pipe Body OD .,-,i15 Wall Thickness in,0.362 Pipe Body Grade IS-135 Pipe Body Torque 0 5.300 10.600 15.800 21.100 26.400 31.700 37.000 42.300 47.500 52.800 58.100 .h-DS bsi Pipe Body Max 580,800558.400 551.400 539,600 522.500 499.600 470.000 432.400 384.500 323.100 234.300 12.200 Tension —: Page 58 Version 1 May, 2015 • • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-46 MPL-46 (Well #2) Plan: MPL-46 wp3 Standard Proposal Report 09 June, 2015 HALLIBURTON Sperry Drilling Services • • HALLIBURTON Project: Milne Point WELL DETAILS:PlanMPL-46 NAD 1927(NA13 ONWNUS) AleskaZone04 Sperry DrillingSite: M Pt L Pad Ground Levet 17.00 Well: Plan MPL-46 ows *EI-w Northing Ending ta6mwe Longitude Slot Wellbore: MPL-46(Well#2) 200 000 6031484.52 545148.08 70°2948.769N 149°3750.907W — Design: MPL-46 wp3 FORMATION TOP DETAILS No formation data is available -1500- -1000— -500—_ 0— Start Build 1.00 CASING DETAILS _ Start Build 3E0 500— 500 TVD TVDSS MD Size Name Start 350.00 hold at 751.60 MD 4147.59 4100.59 6585.44 9-5/8 9 5/8" _------- 4147E0 4100.00 13163.14 5-1/2 5 1/2" 1000— 1000 c_ - -Start DLS 4.00 TFO 129.95 p 1500— 1500 u) - N - rQ+ 2000—: 2000 Start 1499.47 hold a1 2661.88 MD Q 2500 2500— _ 3000 Start DLS 5.00 TFO-100.13 • > - Start 998.51 hold at 12194.63 MD m 3500 --- 2 3000— Start DLS 5.00 TFO-0.77 H 90,0°--, Start 282.79 hold at 6695.14 MD 3500— 00 TD at 13193.14 00 00 y 00 ' 4000— m' Start DLS 5.00 TFO-178.19 c, tpo „�----__ `- ' 8s O O § O 3 0 0 " o o—ss OS 4500— 0 0 0 0 § 0 0 . F 9 5/8" w 5 1/2" 5000— 5500— 6000— -iitliiiilrirrliriiliiii1rrirlriii1prrrjiirr1urrr1iirilriii1rrriliiii1rrri1rrrr1iiii1trr , 1iiir)riiili § ii1rrii1prpr1iiii1rri� -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 8000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section at 143.45°(1250 usft/in) • • HALLIBURTON Project: Milne Point WELL DETAILS:Plan MP-46 Site: M Pt L Pad Ground Leeeh 17.00 Well: Plan MPL-46 +N/-s4-&_W Northing Eastin,a Laemde Longitude Slot Wellbore: MPL-46(Well#2) 0.00 0.00 6031484.52 54514808 70°2548.769N 149°3750.907W 15007 Plan: MPL-46 wp3 REFERENCE INFORMATION J Co-ordinate(N/E)Reference:Well Plan MPL-48,True North 1000- Vertical(TVD)Reference:As-Staked MPL-40 4147.00usf - Measured Depth Reference:As-Staked MPL-40 @ 47.00usft Calculation Method:Minimum Curvature 5007_ ✓9 Starteuild 100 CASING DETAILS 4117 /�A P ND NDSS MD Size Name 0- ___ Stmt 3$000 told at 751 rA MD 4147.59 4100.59 6585.44 9-5/8 9 5/8' 7 StarlDIS 4.00 TFO 129.95.00 4147.00 4100.00 13163.14 5-1/2 51/2' 'w/ -500 1� '4s -10007 Asa 343, -1500- -StartDIS 5.00 TF0-100.13 7 -2000- Start 570.00 told 016078.44 MD 3750 StartSs ixss.00TFo-0.n a -2500- ''Start 782.79 hold el6695.14 MD g 8 -3000- -_-- StartDLS 5.00 TFO-178.19 I Well 2 Heel l--- `'te- ,s-L--___ _____Stmt SDD.00 hold x16994.63 MD tO-3500- 9 5/8" R-4o00- r2 4500- -5000- - Start 978.51 hold at 12194.63 MD -5500- - TD at 13193.14 • -6000- i _ ., 4i 6500- • • - 119'.11 2 T.1 •.,a. - -7000Y - T M Azimuths to True North 5 1/? ` `, I' -7500 Magnetic North:18.96' - Magnetic Field _ Strength:57505.6snT -8000- Dip Angle:81.08° Date:8/14/2015 - Model:BGGM2015 -8500- -1111(111 I I I I I I(111111111111111111111111111.111111111111111 I IIIIIIIIIII 11111111 1111111111111111111111(1111111l I I 1 1111111111111 11111 l ll 1111 11111111(17 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 '7500 8000 8500 9000 West(-)/East(+)(1500 usn) ra Rift'.)}'j) • • Halliburton HALLIBUR AT ON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-46 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-46 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-46 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-46 Survey Calculation Method: Minimum Curvature Wellbore: MPL-46(Well#2) Design: MPL-46 wp3 Project Milne Point,ACT,MILNE POINT 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 M Pt L Pad,TR-13-10 Site Position: Northing: 6,029,799.28 usft Latitude: 70°29'32.230 N From: Map Easting: 544,529.55 usft Longitude: 149°38'9.412 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.34° Well Plan MPL-46 Well Position +N/-S 0.00 usft Northing: 6,031,484.52 usft Latitude: 70°29'48.769 N +E/-W 0.00 usft Easting: 545,148.08 usft Longitude: 149°37'50.907 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 17.00 usft Wellbore MPL-46(Well#2) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/14/2015 18.97 81.08 57,506 Design MPL-46 wp3 Audit Notes: Version: Phase: PLAN Tie On Depth: 30.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 30.00 0.00 0.00 143.45 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (°) (0) (usft) usft (usft) (usft) (1100usft) (°/100usft) 0100usft) (0) 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 0.00 0.00 0.00 0.00 251.60 0.00 0.00 251.60 204.60 0.00 0.00 0.00 0.00 0.00 0.00 451.60 2.00 100.00 451.56 404.56 -0.61 3.44 1.00 1.00 0.00 100.00 751.60 11.00 100.00 749.32 702.32 -6.50 36.85 3.00 3.00 0.00 0.00 1,101.60 11.00 100.00 1,092.89 1,045.89 -18.09 102.62 0.00 0.00 0.00 0.00 2,661.88 55.72 224.69 2,433.32 2,386.32 -556.55 -238.58 4.00 2.87 7.99 129.95 4,161.35 55.72 224.69 3,277.83 3,230.83 -1,437.38 -1,109.98 0.00 0.00 0.00 0.00 6,078.44 85.00 124.11 4,103.42 4,056.42 -2,892.33 -800.71 5.00 1.53 -5.25 -100.13 6,578.44 85.00 124.11 4,147.00 4,100.00 -3,171.69 -388.33 0.00 0.00 0.00 0.00 6,695.14 90.83 124.04 4,151.24 4,104.24 -3,237.00 -291.77 5.00 5.00 -0.07 -0.77 6,977.94 90.83 124.04 4,147.12 4,100.12 -3,395.27 -57.45 0.00 0.00 0.00 0.00 6,994.63 90.00 124.01 4,147.00 4,100.00 -3,404.61 -43.61 5.00 -5.00 -0.16 -178.19 12,194.63 90.00 124.01 4,147.00 4,100.00 -6,313.17 4,266.87 0.00 0.00 0.00 0.00 13,193.14 90.00 124.01 4,147.00 4,100.00 -6,871.67 5,094.58 0.00 0.00 0.00 0.00 6/9/2015 5:28:54PM Page 2 COMPASS 5000.1 Build 73 • Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-46 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-46 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-46 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-46 Survey Calculation Method: Minimum Curvature Wellbore: MPL-46(Well#2) Design: MPL-46 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +El-W Northing Easting DLS Vert Section (usft) (°) (^) (usft) usft (usft) (usft) (usft) (usft) -17.00 30.00 0.00 0.00 30.00 -17.00 0.00 0.00 6,031,484.52 545,148.08 0.00 0.00 100.00 0.00 0.00 100.00 53.00 0.00 0.00 6,031,484.52 545,148.08 0.00 0.00 200.00 0.00 0.00 200.00 153.00 0.00 0.00 6,031,484.52 545,148.08 0.00 0.00 251.60 0.00 0.00 251.60 204.60 0.00 0.00 6,031,484.52 545,148.08 0.00 0.00 300.00 0.48 100.00 300.00 253.00 -0.04 0.20 6,031,484.49 545,148.28 1.00 0.15 400.00 1.48 100.00 399.98 352.98 -0.33 1.89 6,031,484.20 545,149.97 1.00 1.40 451.60 2.00 100.00 451.56 404.56 -0.61 3.44 6,031,483.93 545,151.52 1.00 2.53 500.00 3.45 100.00 499.90 452.90 -1.01 5.70 6,031,483.55 545,153.79 3.00 4.21 600.00 6.45 100.00 599.52 552.52 -2.50 14.20 6,031,482.10 545,162.30 3.00 10.47 700.00 9.45 100.00 698.55 651.55 -4.91 27.83 6,031,479.78 545,175.93 3.00 20.51 751.60 11.00 100.00 749.32 702.32 -6.50 36.85 6,031,478.25 545,184.96 3.00 27.16 800.00 11.00 100.00 796.84 749.84 -8.10 45.94 6,031,476.70 545,194.07 0.00 33.87 900.00 11.00 100.00 895.00 848.00 -11.41 64.73 6,031,473.50 545,212.88 0.00 47.72 1,000.00 11.00 100.00 993.16 946.16 -14.73 83.52 6,031,470.30 545,231.68 0.00 61.58 1,101.60 11.00 100.00 1,092.89 1,045.89 -18.09 102.62 6,031,467.05 545,250.79 0.00 75.65 1,200.00 8.99 119.68 1,189.82 1,142.82 -23.53 118.55 6,031,461.71 545,266.75 4.00 89.51 1,300.00 8.45 146.07 1,288.71 1,241.71 -33.50 129.44 6,031,451.81 545,277.71 4.00 104.00 1,400.00 9.69 170.44 1,387.49 1,340.49 -47.90 134.94 6,031,437.45 545,283.29 4.00 118.84 1,500.00 12.17 187.17 1,485.70 1,438.70 -66.66 135.02 6,031,418.69 545,283.49 4.00 133.96 1,600.00 15.30 197.75 1,582.84 1,535.84 -89.68 129.68 6,031,395.63 545,278.29 4.00 149.28 1,700.00 18.75 204.66 1,678.46 1,631.46 -116.86 118.95 6,031,368.39 545,267.73 4.00 164.72 1,800.00 22.39 209.44 1,772.07 1,725.07 -148.07 102.88 6,031,337.09 545,251.85 4.00 180.22 1,900.00 26.12 212.93 1,863.23 1,816.23 -183.14 81.55 6,031,301.89 545,230.73 4.00 195.69 2,000.00 29.92 215.59 1,951.50 1,904.50 -221.92 55.06 6,031,262.96 545,204.48 4.00 211.06 2,100.00 33.76 217.70 2,036.43 1,989.43 -264.21 23.54 6,031,220.49 545,173.22 4.00 226.26 2,200.00 37.64 219.42 2,117.63 2,070.63 -309.80 -12.86 6,031,174.68 545,137.10 4.00 241.21 2,300.00 41.53 220.86 2,194.69 2,147.69 -358.48 -53.96 6,031,125.76 545,096.31 4.00 255.83 2,400.00 45.44 222.10 2,267.23 2,220.23 -410.00 -99.55 6,031,073.96 545,051.03 4.00 270.07 2,500.00 49.36 223.18 2,334.91 2,287.91 -464.12 -149.42 6,031,019.55 545,001.50 4.00 283.84 2,600.00 53.29 224.15 2,397.39 2,350.39 -520.57 -203.32 6,030,962.78 544,947.95 4.00 297.09 2,661.88 55.72 224.69 2,433.32 2,386.32 -556.55 -238.58 6,030,926.59 544,912.91 4.00 304.99 2,700.00 55.72 224.69 2,454.79 2,407.79 -578.94 -260.73 6,030,904.07 544,890.89 0.00 309.78 2,800.00 55.72 224.69 2,511.11 2,464.11 -637.68 -318.85 6,030,844.98 544,833.14 0.00 322.36 2,900.00 55.72 224.69 2,567.43 2,520.43 -696.42 -376.96 6,030,785.89 544,775.39 0.00 334.94 3,000.00 55.72 224.69 2,623.75 2,576.75 -755.17 -435.07 6,030,726.80 544,717.64 0.00 347.52 3,100.00 55.72 224.69 2,680.07 2,633.07 -813.91 -493.19 6,030,667.71 544,659.89 0.00 360.10 3,200.00 55.72 224.69 2,736.39 2,689.39 -872.65 -551.30 6,030,608.62 544,602.14 0.00 372.67 3,300.00 55.72 224.69 2,792.71 2,745.71 -931.40 -609.42 6,030,549.53 544,544.39 0.00 385.25 3,400.00 55.72 224.69 2,849.03 2,802.03 -990.14 -667.53 6,030,490.44 544,486.64 0.00 397.83 3,500.00 55.72 224.69 2,905.35 2,858.35 -1,048.88 -725.64 6,030,431.35 544,428.89 0.00 410.41 3,600.00 55.72 224.69 2,961.67 2,914.67 -1,107.63 -783.76 6,030,372.26 544,371.14 0.00 422.99 3,700.00 55.72 224.69 3,018.00 2,971.00 -1,166.37 -841.87 6,030,313.17 544,313.39 0.00 435.56 3,800.00 55.72 224.69 3,074.32 3,027.32 -1,225.11 -899.99 6,030,254.09 544,255.64 0.00 448.14 3,900.00 55.72 224.69 3,130.64 3,083.64 -1,283.85 -958.10 6,030,195.00 544,197.89 0.00 460.72 4,000.00 55.72 224.69 3,186.96 3,139.96 -1,342.60 -1,016.21 6,030,135.91 544,140.14 0.00 473.30 6/9/2015 5:28:54PM Page 3 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-46 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-46 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-46 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-46 Survey Calculation Method: Minimum Curvature Wellbore: MPL-46(Well#2) Design: MPL-46 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,196.28 4,100.00 55.72 224.69 3,243.28 3,196.28 -1,401.34 -1,074.33 6,030,076.82 544,082.39 0.00 485.88 4,161.35 55.72 224.69 3,277.83 3,230.83 -1,437.38 -1,109.98 6,030,040.57 544,046.96 0.00 493.59 4,200.00 55.40 222.38 3,299.69 3,252.69 -1,460.48 -1,131.94 6,030,017.33 544,025.15 5.00 499.08 4,300.00 54.79 216.33 3,356.95 3,309.95 -1,523.84 -1,183.91 6,029,953.67 543,973.56 5.00 519.02 4,400.00 54.47 210.21 3,414.87 3,367.87 -1,591.96 -1,228.61 6,029,885.29 543,929.28 5.00 547.11 4,500.00 54.47 204.06 3,473.02 3,426.02 -1,664.32 -1,265.70 6,029,812.70 543,892.63 5.00 583.16 4,600.00 54.78 197.94 3,530.95 3,483.95 -1,740.39 -1,294.90 6,029,736.47 543,863.90 5.00 626.87 4,700.00 55.39 191.89 3,588.22 3,541.22 -1,819.57 -1,315.97 6,029,657.17 543,843.31 5.00 677.93 4,800.00 56.30 185.95 3,644.40 3,597.40 -1,901.26 -1,328.77 6,029,575.41 543,831.01 5.00 735.93 4,900.00 57.48 180.15 3,699.05 3,652.05 -1,984.85 -1,333.19 6,029,491.81 543,827.10 5.00 800.45 5,000.00 58.93 174.51 3,751.77 3,704.77 -2,069.69 -1,329.20 6,029,407.00 543,831.61 5.00 870.98 5,100.00 60.61 169.06 3,802.15 3,755.15 -2,155.15 -1,316.83 6,029,321.62 543,844.49 5.00 946.99 5,200.00 62.50 163.80 3,849.80 3,802.80 -2,240.57 -1,296.18 6,029,236.34 543,865.66 5.00 1,027.91 5,300.00 64.59 158.72 3,894.37 3,847.37 -2,325.29 -1,267.39 6,029,151.80 543,894.96 5.00 1,113.11 5,400.00 66.84 153.83 3,935.52 3,888.52 -2,408.69 -1,230.70 6,029,068.64 543,932.15 5.00 1,201.96 5,500.00 69.24 149.10 3,972.93 3,925.93 -2,490.11 -1,186.38 6,028,987.49 543,976.96 5.00 1,293.76 5,600.00 71.77 144.52 4,006.31 3,959.31 -2,568.95 -1,134.77 6,028,908.98 544,029.04 5.00 1,387.83 5,700.00 74.40 140.07 4,035.42 3,988.42 -2,644.60 -1,076.26 6,028,833.69 544,088.01 5.00 1,483.45 5,800.00 77.12 135.74 4,060.03 4,013.03 -2,716.48 -1,011.29 6,028,762.21 544,153.40 5.00 1,579.88 5,900.00 79.90 131.51 4,079.96 4,032.96 -2,784.05 -940.36 6,028,695.08 544,224.73 5.00 1,676.41 6,000.00 82.74 127.34 4,095.05 4,048.05 -2,846.80 -864.02 6,028,632.80 544,301.45 5.00 1,772.28 6,078.44 85.00 124.11 4,103.42 4,056.42 -2,892.33 -800.71 6,028,587.66 544,365.03 5.00 1,846.56 6,100.00 85.00 124.11 4,105.30 4,058.30 -2,904.38 -782.93 6,028,575.73 544,382.88 0.00 1,866.82 6,200.00 85.00 124.11 4,114.02 4,067.02 -2,960.25 -700.46 6,028,520.36 544,465.68 0.00 1,960.82 6,300.00 85.00 124.11 4,122.73 4,075.73 -3,016.12 -617.98 6,028,465.00 544,548.49 0.00 2,054.83 6,400.00 85.00 124.11 4,131.45 4,084.45 -3,071.99 -535.50 6,028,409.63 544,631.30 0.00 2,148.83 6,500.00 85.00 124.11 4,140.16 4,093.16 -3,127.86 -453.03 6,028,354.27 544,714.10 0.00 2,242.83 6,578.44 85.00 124.11 4,147.00 4,100.00 -3,171.69 -388.33 6,028,310.84 544,779.06 0.00 2,316.57 6,585.44 85.35 124.11 4,147.59 4,100.59 -3,175.60 -382.56 6,028,306.97 544,784.85 5.00 2,323.15 9 5/8" 6,600.00 86.08 124.10 4,148.68 4,101.68 -3,183.74 -370.53 6,028,298.90 544,796.92 5.00 2,336.85 6,695.14 90.83 124.04 4,151.24 4,104.24 -3,237.00 -291.77 6,028,246.12 544,876.00 5.00 2,426.54 6,700.00 90.83 124.04 4,151.17 4,104.17 -3,239.72 -287.75 6,028,243.43 544,880.04 0.00 2,431.12 6,800.00 90.83 124.04 4,149.71 4,102.71 -3,295.69 -204.89 6,028,187.97 544,963.23 0.00 2,525.43 , 6,900.00 90.83 124.04 4,148.26 4,101.26 -3,351.65 -122.03 6,028,132.51 545,046.42 0.00 2,619.73 6,977.94 90.83 124.04 4,147.12 4,100.12 -3,395.27 -57.45 6,028,089.29 545,111.26 0.00 2,693.23 6,994.63 90.00 124.01 4,147.00 4,100.00 -3,404.61 -43.61 6,028,080.04 545,125.15 5.00 2,708.98 7,000.00 90.00 124.01 4,147.00 4,100.00 -3,407.62 -39.16 6,028,077.06 545,129.62 0.00 2,714.04 7,100.00 90.00 124.01 4,147.00 4,100.00 -3,463.55 43.73 6,028,021.64 545,212.84 0.00 2,808.34 7,200.00 90.00 124.01 4,147.00 4,100.00 -3,519.48 126.62 6,027,966.22 545,296.06 0.00 2,902.64 7,300.00 90.00 124.01 4,147.00 4,100.00 -3,575.42 209.52 6,027,910.79 545,379.29 0.00 2,996.94 7,400.00 90.00 124.01 4,147.00 4,100.00 -3,631.35 292.41 6,027,855.37 545,462.51 0.00 3,091.24 7,500.00 90.00 124.01 4,147.00 4,100.00 -3,687.28 375.31 6,027,799.94 545,545.74 0.00 3,185.54 7,600.00 90.00 124.01 4,147.00 4,100.00 -3,743.22 458.20 6,027,744.52 545,628.96 0.00 3,279.84 7,700.00 90.00 124.01 4,147.00 4,100.00 -3,799.15 541.09 6,027,689.10 545,712.18 0.00 3,374.15 6/9/2015 5:28:54PM Page 4 COMPASS 5000.1 Build 73 Halliburton HAL L I B U R 10 I'd Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-46 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-46 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-46 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-46 Survey Calculation Method: Minimum Curvature Wellbore: MPL-46(Well#2) Design: MPL-46 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 4,100.00 7,800.00 90.00 124.01 4,147.00 4,100.00 -3,855.09 623.99 6,027,633.67 545,795.41 0.00 3,468.45 7,900.00 90.00 124.01 4,147.00 4,100.00 -3,911.02 706.88 6,027,578.25 545,878.63 0.00 3,562.75 8,000.00 90.00 124.01 4,147.00 4,100.00 -3,966.95 789.78 6,027,522.82 545,961.86 0.00 3,657.05 8,100.00 90.00 124.01 4,147.00 4,100.00 -4,022.89 872.67 6,027,467.40 546,045.08 0.00 3,751.35 8,200.00 90.00 124.01 4,147.00 4,100.00 -4,078.82 955.56 6,027,411.98 546,128.31 0.00 3,845.65 8,300.00 90.00 124.01 4,147.00 4,100.00 -4,134.75 1,038.46 6,027,356.55 546,211.53 0.00 3,939.95 8,400.00 90.00 124.01 4,147.00 4,100.00 -4,190.69 1,121.35 6,027,301.13 546,294.75 0.00 4,034.25 8,500.00 90.00 124.01 4,147.00 4,100.00 -4,246.62 1,204.25 6,027,245.71 546,377.98 0.00 4,128.55 8,600.00 90.00 124.01 4,147.00 4,100.00 -4,302.56 1,287.14 6,027,190.28 546,461.20 0.00 4,222.85 8,700.00 90.00 124.01 4,147.00 4,100.00 -4,358.49 1,370.03 6,027,134.86 546,544.43 0.00 4,317.15 8,800.00 90.00 124.01 4,147.00 4,100.00 -4,414.42 1,452.93 6,027,079.43 546,627.65 0.00 4,411.45 8,900.00 90.00 124.01 4,147.00 4,100.00 -4,470.36 1,535.82 6,027,024.01 546,710.87 0.00 4,505.75 9,000.00 90.00 124.01 4,147.00 4,100.00 -4,526.29 1,618.72 6,026,968.59 546,794.10 0.00 4,600.05 9,100.00 90.00 124.01 4,147.00 4,100.00 -4,582.22 1,701.61 6,026,913.16 546,877.32 0.00 4,694.35 9,200.00 90.00 124.01 4,147.00 4,100.00 -4,638.16 1,784.50 6,026,857.74 546,960.55 0.00 4,788.66 9,300.00 90.00 124.01 4,147.00 4,100.00 -4,694.09 1,867.40 6,026,802.32 547,043.77 0.00 4,882.96 9,400.00 90.00 124.01 4,147.00 4,100.00 -4,750.03 1,950.29 6,026,746.89 547,126.99 0.00 4,977.26 9,500.00 90.00 124.01 4,147.00 4,100.00 -4,805.96 2,033.19 6,026,691.47 547,210.22 0.00 5,071.56 9,600.00 90.00 124.01 4,147.00 4,100.00 -4,861.89 2,116.08 6,026,636.04 547,293.44 0.00 5,165.86 9,700.00 90.00 124.01 4,147.00 4,100.00 -4,917.83 2,198.97 6,026,580.62 547,376.67 0.00 5,260.16 9,800.00 90.00 124.01 4,147.00 4,100.00 -4,973.76 2,281.87 6,026,525.20 547,459.89 0.00 5,354.46 9,900.00 90.00 124.01 4,147.00 4,100.00 -5,029.69 2,364.76 6,026,469.77 547,543.11 0.00 5,448.76 10,000.00 90.00 124.01 4,147.00 4,100.00 -5,085.63 2,447.66 6,026,414.35 547,626.34 0.00 5,543.06 10,100.00 90.00 124.01 4,147.00 4,100.00 -5,141.56 2,530.55 6,026,358.92 547,709.56 0.00 5,637.36 10,200.00 90.00 124.01 4,147.00 4,100.00 -5,197.50 2,613.44 6,026,303.50 547,792.79 0.00 5,731.66 10,300.00 90.00 124.01 4,147.00 4,100.00 -5,253.43 2,696.34 6,026,248.08 547,876.01 0.00 5,825.96 10,400.00 90.00 124.01 4,147.00 4,100.00 -5,309.36 2,779.23 6,026,192.65 547,959.23 0.00 5,920.26 10,500.00 90.00 124.01 4,147.00 4,100.00 -5,365.30 2,862.13 6,026,137.23 548,042.46 0.00 6,014.56 10,600.00 90.00 124.01 4,147.00 4,100.00 -5,421.23 2,945.02 6,026,081.81 548,125.68 0.00 6,108.87 10,700.00 90.00 124.01 4,147.00 4,100.00 -5,477.16 3,027.91 6,026,026.38 548,208.91 0.00 6,203.17 10,800.00 90.00 124.01 4,147.00 4,100.00 -5,533.10 3,110.81 6,025,970.96 548,292.13 0.00 6,297.47 10,900.00 90.00 124.01 4,147.00 4,100.00 -5,589.03 3,193.70 6,025,915.53 548,375.36 0.00 6,391.77 11,000.00 90.00 124.01 4,147.00 4,100.00 -5,644.97 3,276.60 6,025,860.11 548,458.58 0.00 6,486.07 11,100.00 90.00 124.01 4,147.00 4,100.00 -5,700.90 3,359.49 6,025,804.69 548,541.80 0.00 6,580.37 11,200.00 90.00 124.01 4,147.00 4,100.00 -5,756.83 3,442.38 6,025,749.26 548,625.03 0.00 6,674.67 11,300.00 90.00 124.01 4,147.00 4,100.00 -5,812.77 3,525.28 6,025,693.84 548,708.25 0.00 6,768.97 11,400.00 90.00 124.01 4,147.00 4,100.00 -5,868.70 3,608.17 6,025,638.41 548,791.48 0.00 6,863.27 11,500.00 90.00 124.01 4,147.00 4,100.00 -5,924.63 3,691.07 6,025,582.99 548,874.70 0.00 6,957.57 11,600.00 90.00 124.01 4,147.00 4,100.00 -5,980.57 3,773.96 6,025,527.57 548,957.92 0.00 7,051.87 11,700.00 90.00 124.01 4,147.00 4,100.00 -6,036.50 3,856.85 6,025,472.14 549,041.15 0.00 7,146.17 11,800.00 90.00 124.01 4,147.00 4,100.00 -6,092.44 3,939.75 6,025,416.72 549,124.37 0.00 7,240.47 11,900.00 90.00 124.01 4,147.00 4,100.00 -6,148.37 4,022.64 6,025,361.30 549,207.60 0.00 7,334.77 12,000.00 90.00 124.01 4,147.00 4,100.00 -6,204.30 4,105.54 6,025,305.87 549,290.82 0.00 7,429.07 12,100.00 90.00 124.01 4,147.00 4,100.00 -6,260.24 4,188.43 6,025,250.45 549,374.04 0.00 7,523.38 12,194.63 90.00 124.01 4,147.00 4,100.00 -6,313.17 4,266.87 6,025,198.00 549,452.80 0.00 7,612.61 6/9/2015 5:28:54PM Page 5 COMPASS 5000.1 Build 73 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Plan MPL-46 Company: Hilcorp Energy Company TVD Reference: As-Staked MPL-46 @ 47.00usft Project: Milne Point MD Reference: As-Staked MPL-46 @ 47.00usft Site: M Pt L Pad North Reference: True Well: Plan MPL-46 Survey Calculation Method: Minimum Curvature Wellbore: MPL-46(Well#2) Design: MPL-46 wp3 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 4,100.00 12,200.00 90.00 124.01 4,147.00 4,100.00 -6,316.17 4,271.32 6,025,195.02 549,457.27 0.00 7,617.68 12,300.00 90.00 124.01 4,147.00 4,100.00 -6,372.10 4,354.22 6,025,139.60 549,540.49 0.00 7,711.98 12,400.00 90.00 124.01 4,147.00 4,100.00 -6,428.04 4,437.11 6,025,084.18 549,623.72 0.00 7,806.28 12,500.00 90.00 124.01 4,147.00 4,100.00 -6,483.97 4,520.01 6,025,028.75 549,706.94 0.00 7,900.58 12,600.00 90.00 124.01 4,147.00 4,100.00 -6,539.91 4,602.90 6,024,973.33 549,790.16 0.00 7,994.88 12,700.00 90.00 124.01 4,147.00 4,100.00 -6,595.84 4,685.79 6,024,917.91 549,873.39 0.00 8,089.18 12,800.00 90.00 124.01 4,147.00 4,100.00 -6,651.77 4,768.69 6,024,862.48 549,956.61 0.00 8,183.48 12,900.00 90.00 124.01 4,147.00 4,100.00 -6,707.71 4,851.58 6,024,807.06 550,039.84 0.00 8,277.78 13,000.00 90.00 124.01 4,147.00 4,100.00 -6,763.64 4,934.48 6,024,751.63 550,123.06 0.00 8,372.08 13,100.00 90.00 124.01 4,147.00 4,100.00 -6,819.57 5,017.37 6,024,696.21 550,206.28 0.00 8,466.38 13,193.14 90.00 124.01 4,147.00 4,100.00 -6,871.67 5,094.58 6,024,644.59 550,283.80 0.00 8,554.22 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Well 2 Heel 0.00 0.35 4,147.00 -3,171.69 -388.33 6,028,310.84 544,779.06 -plan hits target center -Circle(radius 100.00) Well 2 Toe 0.00 0.35 4,147.00 -6,313.17 4,266.87 6,025,198.00 549,452.80 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 6,585.44 4,147.59 9 5/8" 9-5/8 12-1/4 13,200.00 5 1/2" 5-1/2 8-1/2 6/9/2015 5:28:54PM Page 6 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company Milne Point M Pt L Pad Plan MPL-46 MPL-46(Well#2) MPL-46 wp3 Sperry Drilling Services Clearance Summary Anticollision Report 09 June,2015 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-46-MPL-46(Well#2)-MPL-46 wp3 Well Coordinates: 6,031,484.52 N,545,148.08E(70°29'48.77"N,149°37'50.91"W) Datum Height: As-Staked MPL-46 @ 47.00usft Scan Range: 0.00 to 13,193.14 usft.Measured Depth. Scan Radius Is 1,516.31 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:73 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services • • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-46-MPL-46 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: M Pt L Pad-Plan MPL-46-MPL-46(Well 42)-MPL-46 wp3 Scan Range:0.00 to 13,193.14 usft.Measured Depth. Scan Radius is 1,516.31 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft M Pt L Pad MPL-02-MPL-02-MPL-02 30.00 335.07 30.00 334.16 39.00 367.464 Centre Distance Pass- MPL-02-MPL-02-MPL-02 300.00 335.45 300.00 332.22 308.70 103.772 Ellipse Separation Pass- MPL-02-MPL-02-MPL-02 2,425.00 396.09 2,425.00 376.02 2,295.04 19.730 Clearance Factor Pass- MPL-02-MPL-02A-MPL-02A 30.00 335.07 30.00 334.44 39.00 531.352 Centre Distance Pass- MPL-02-MPL-02A-MPL-02A 300.00 335.45 300.00 332.50 308.70 113.661 Ellipse Separation Pass- MPL-02-MPL-02A-MPL-02A 2,425.00 396.09 2,425.00 376.30 2,295.04 20.010 Clearance Factor Pass- MPL-02-MPL-02AL1-MPL-02AL1 30.00 335.07 30.00 334.46 39.00 549.506 Centre Distance Pass- MPL-02-MPL-02AL1-MPL-02AL1 300.00 335.45 300.00 332.52 308.70 114.469 Ellipse Separation Pass- MPL-02-MPL-02AL1-MPL-02AL1 2,425.00 396.09 2,425.00 376.32 2,295.04 20.031 Clearance Factor Pass- MPL-02-MPL-02AL2-MPL-02AL2 30.00 335.07 30.00 334.16 39.00 367.464 Centre Distance Pass- MPL-02-MPL-02AL2-MPL-02AL2 300.00 335.45 300.00 332.22 308.70 103.772 Ellipse Separation Pass- MPL-02-MPL-02AL2-MPL-02AL2 2,425.00 396.09 2,425.00 376.02 2,295.04 19.730 Clearance Factor Pass- MPL-02-MPL-02AP81-MPL-02APB1 30.00 335.07 30.00 334.16 39.00 367.464 Centre Distance Pass- MPL-02-MPL-02APB1-MPL-02APB1 300.00 335.45 300.00 332.22 308.70 103.772 Ellipse Separation Pass- MPL-02-MPL-02APB1-MPL-02APB1 2,425.00 396.09 2,425.00 376.02 2,295.04 19.730 Clearance Factor Pass- MPL-02-MPL-02APB2-MPL-02APB2 30.00 335.07 30.00 334.16 39.00 367.464 Centre Distance Pass- MPL-02-MPL-02APB2-MPL-02APB2 300.00 335.45 300.00 332.22 308.70 103.772 Ellipse Separation Pass- MPL-02-MPL-02APB2-MPL-02APB2 2,425.00 396.09 2,425.00 376.02 2,295.04 19.730 Clearance Factor Pass- MPL-04-MPL-04-MPL-04 30.00 204.11 30.00 203,19 19.00 223.835 Centre Distance Pass- MPL-04-MPL-04-MPL-04 275.00 205.16 275,00 202.17 262.89 68.552 Ellipse Separation Pass- MPL-04-MPL-04-MPL-04 875.00 270.20 875.00 263.40 842.63 39.745 Clearance Factor Pass- MPL-05-MPL-05-MPL-05 30.00 144.60 30.00 143.69 39.00 158.577 Centre Distance Pass- MPL-05-MPL-05-MPL-05 250.00 145.90 250.00 143.14 257.80 52.936 Ellipse Separation Pass- MPL-05-MPL-05-MPL-05 950.00 217.29 950.00 209.92 952.53 29.493 Clearance Factor Pass- MPL-06-MPL-06-MPL-06 1,666.92 212.94 1,666.92 200.15 1,712.48 16.646 Ellipse Separation Pass- MPL-06-MPL-06-MPL-06 1,725.00 216.32 1,725.00 203.16 1,755.36 16.441 Clearance Factor Pass- MPL-07-MPL-07-MPL-07 30.00 133.60 30.00 132.69 39.00 146.512 Centre Distance Pass- MPL-07-MPL-07-MPL-07 300.00 135.37 300.00 132.14 307.75 41.942 Ellipse Separation Pass- 09 June,2015-- 17:30 Page 2 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-46-MPL-46 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-46-MPL-46(Well 92)-MPL-46 wp3 Scan Range:0.00 to 13,193.14 usft.Measured Depth. Scan Radius is 1,516.31 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on She Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-07-MPL-07-MPL-07 925.00 190.90 925.00 183.56 903.91 26.019 Clearance Factor Pass- MPL-09-MPL-09-MPL-09 275.00 236.90 275.00 233.90 284.25 78.969 Centre Distance Pass- MPL-09-MPL-09-MPL-09 400.00 237.34 400.00 233.38 409.41 59.897 Ellipse Separation Pass- MPL-09-MPL-09-MPL-09 1,650.00 371.13 1,650.00 358.94 1,640.19 30427 Clearance Factor Pass- MPL-09-MPL-09A-MPL-09A 275.00 236.90 275.00 234.20 284.25 87.812 Centre Distance Pass- MPL-09-MPL-09A-MPL-09A 400.00 237.34 400.00 233.68 409.41 64.840 Ellipse Separation Pass- MPL-09-MPL-09A-MPL-09A 1,650.00 371.13 1,650.00 359.24 1,640.19 31.200 Clearance Factor Pass- MPL-09-MPL-09APB1-MPL-09APB1 275.00 236.90 275.00 233.90 284.25 78.969 Centre Distance Pass- MPL-09-MPL-09APB1-MPL-09APB1 400.00 237.34 400.00 233.38 409.41 59.897 Ellipse Separation Pass- MPL-09-MPL-09APB1-MPL-09APB1 1,650.00 371.13 1,650.00 358.94 1,640.19 30.427 Clearance Factor Pass- MPL-10-MPL-10-MPL-10 183.53 183.59 183.53 181.48 192.53 87.182 Centre Distance Pass- MPL-10-MPL-10-MPL-10 400.00 184.00 400.00 180.04 408.92 46.466 Ellipse Separation Pass- MPL-10-MPL-10-MPL-10 1,475.00 284.66 1,475.00 273.60 1,469.98 25.746 Clearance Factor Pass- MPL-11-MPL-11-MPL-11 312.33 83.20 312.33 78.60 317.06 18.086 Centre Distance Pass- MPL-11-MPL-11-MPL-11 450.00 84.10 450.00 77.90 455.61 13.564 Ellipse Separation Pass- MPL-11-MPL-11-MPL-11 1,050.00 135.11 1,050.00 121.40 1,058.42 9.852 Clearance Factor Pass- MPL-12-MPL-12-MPL-12 2,193.91 71.89 2,193.91 48.74 2,156.88 3.105 Clearance Factor Pass- MPL-34-MPL-34-MPL-34 254.97 373.56 254.97 370.76 245.06 133.444 Centre Distance Pass- MPL-34-MPL-34-MPL-34 300.00 373.72 300.00 370.49 290.19 115.893 Ellipse Separation Pass- MPL-34-MPL-34-MPL-34 4,300.00 558.50 4,300.00 503.35 4,144.25 10.127 Clearance Factor Pass- MPL-35-MPL-35-MPL-35 230.80 233.87 230.80 231.31 234.20 91.352 Centre Distance Pass- MPL-35-MPL-35-MPL-35 300.00 234.19 300.00 230.98 302.25 72.849 Ellipse Separation Pass- MPL-35-MPL-35-MPL-35 3,400.00 27625 3,400.00 255.51 2,997.68 13.321 Clearance Factor Pass- MPL-35-MPL-35A-MPL-35A 230.80 233.87 230.80 231.31 235.00 91.352 Centre Distance Pass- MPL-35-MPL-35A-MPL-35A 300.00 234.19 300.00 230.98 303.05 72.849 Ellipse Separation Pass- MPL-35-MPL-35A-MPL-35A 3,400.00 276.25 3,400.00 255.51 2,998.48 13.321 Clearance Factor Pass- MPL-35-MPL-35APB1-MPL-35APB1 230.80 233.87 230.80 231.31 235.00 91.352 Centre Distance Pass- MPL-35-MPL-35APB1-MPL-35APB1 300.00 234.19 300.00 230.98 303.05 72.849 Ellipse Separation Pass- MPL-35-MPL-35APB1-MPL-35APB1 3,400.00 276.25 3,400.00 255.51 2,998.48 13.321 Clearance Factor Pass- MPL-35-MPL-35APB2-MPL-35APB2 230.80 233.87 230.80 231.31 235.00 91.352 Centre Distance Pass- MPL-35-MPL-35APB2-MPL-35APB2 300,00 234.19 300.00 230.98 303.05 72.849 Ellipse Separation Pass- 09 June,2015-17:30 Page 3 of 7 COMPASS • • • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-46-MPL-46 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-46-MPL-46(Well#2)-MPL-46 wp3 Scan Range: 0.00 to 13,193.14 usft.Measured Depth. Scan Radius is 1,516.31 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft MPL-35-MPL-35APB2-MPL-35APB2 3,400.00 276.25 3,400.00 255.51 2,998.48 13.321 Clearance Factor Pass- MPL-35-MPL-35APB3-MPL-35APB3 230.80 233.87 230.80 231.31 235.00 91.352 Centre Distance Pass- MPL-35-MPL-35APB3-MPL-35APB3 300.00 234.19 300.00 230.98 303.05 72.849 Ellipse Separation Pass- MPL-35-MPL-35APB3-MPL-35APB3 3,400.00 276.25 3,400.00 255.51 2,998.48 13.321 Clearance Factor Pass- MPL-35-Plan MPL-35B-MPL-35B wp1 230.80 233.87 230.80 231.48 234.20 97.926 Centre Distance Pass- MPL-35-Plan MPL-35B-MPL-35B wp1 300.00 234.19 300.00 231.15 302.25 76.964 Ellipse Separation Pass- MPL-35-Plan MPL-35B-MPL-35B wp1 3,400.00 276.25 3,400.00 255.69 2,997.68 13.432 Clearance Factor Pass- MPL-37-MPL-37-MPL-37 2,925.25 71.94 2,925.25 44.43 2,718.64 2.615 Centre Distance Pass- MPL-37-MPL-37-MPL-37 2,975.00 73.63 2,975.00 41.65 2,765.60 2.303 Ellipse Separation Pass- MPL-37-MPL-37-MPL-37 3,05000 81.30 3,050.00 44.34 2,837.39 2.200 Clearance Factor Pass- MPL-37-MPL-37A-MPL-37A 2,925.25 71.94 2,925.25 44.41 2,727.84 2.614 Centre Distance Pass- MPL-37-MPL-37A-MPL-37A 2,975.00 73.63 2,975.00 41.64 2,774.80 2.301 Ellipse Separation Pass- MPL-37-MPL-37A-MPL-37A 3,050.00 81.30 3,050.00 44.31 2,846.59 2.198 Clearance Factor Pass- MPL-37-Plan MPL-37B-MPL-37B WP2 2,925.25 71.94 2,925.25 44.63 2,718.64 2.635 Centre Distance Pass- MPL-37-Plan MPL-37B-MPL-37B WP2 2,975.00 73.63 2,975.00 41.86 2,765.60 2.318 Ellipse Separation Pass- MPL-37-Plan MPL-37B-MPL-37B WP2 3,050.00 81.30 3,050.00 44.54 2,837.39 2.212 Clearance Factor Pass- MPL-42-MPL-42-MPL-42 1,907.92 261.30 1,907.92 250.73 1,938.59 24.710 Centre Distance Pass- MPL-42-MPL-42-MPL-42 1,925.00 261.36 1,925.00 250.72 1,954.83 24.551 Ellipse Separation Pass- MPL-42-MPL-42-MPL-42 8,500.00 1,223.43 8,500.00 1,095.98 7,202.91 9.599 Clearance Factor Pass- MPL-45-MPL-45-MPL-45 3,265.45 125.06 3,265.45 106.71 3,263.73 6.815 Centre Distance Pass- MPL-45-MPL-45-MPL-45 3,325.00 129.25 3,325.00 105.26 3,314.91 5.388 Ellipse Separation Pass- MPL-45-MPL-45-MPL-45 3,50000 181.44 3,500.00 136.48 3,460.81 4.035 Clearance Factor Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 705.41 153.61 705A1 148.37 713.93 29.328 Centre Distance Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 725.00 153.67 725.00 148.30 733.74 28.636 Ellipse Separation Pass- Plan MPL-47-MPL-47(Well#4)-MPL-47 wp3 1,575.00 327.31 1,575.00 312.87 1,500.00 22.671 Clearance Factor Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 250.00 26.11 250.00 23.48 250.00 9.930 Centre Distance Pass- Plan MPL-48-MPL-48(Well#3)-MPL-48 wp3 300.00 26.29 300.00 23.22 300.00 8.562 Ellipse Separation Pass- Plan MPL-08-MPL-48(Well#3(-MPL-48 wp3 13,025.00 1,115.58 13,025.00 829.42 13,154.60 3.898 Clearance Factor Pass- Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 3,100.00 93.22 3,100.00 61.76 3,029.85 2.963 Clearance Factor Pass- Plan MPL-49-MPL-49(Well#1)-MPL-49 wp3 3,110.70 93.17 3,110.70 61.75 3,040.13 2.965 Ellipse Separation Pass- 09 June,2015-17:30 Page 4 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-46-MPL-46 wp3 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:M Pt L Pad-Plan MPL-46-MPL-46(Weil#2)-MPL-46 wp3 Scan Range: 0.00 to 13,193.14 usft.Measured Depth. Scan Radius is 1,516.31 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 250.00 55.48 250.00 52.85 250.80 21.074 Centre Distance Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 300.00 55.66 300.00 52.58 300.80 18.101 Ellipse Separation Pass- Plan MPL-50-MPL-50(well#5)-MPL-50 wp3 550.00 63.85 550.00 59.52 550.40 14.736 Clearance Factor Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 30.00 300.00 MPL-46 wp3 SRG-SS 300.00 6,585.44 MPL-46 wp3 MWD+IFR2+MS+sag 6,585.44 13,193.14 MPL-46wp3 MWD+IFR2+MS+sag Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 09 June,2015- 1730 Page 5 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-46-MPL-46 wp3 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to As-Staked MPL-46 @ 47.00usft. Northing and Easting are relative to Plan MPL-46. Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04. Central Meridian is-150.00`,Grid Convergence at Surface is:0.35°. -4- MPL-04 MPL-04 MPL-04V1 Ladder Plot $ MPL07,MPL07,MPL-07V1 -0- MPL-05,MPL-05,MPL-05 V1 r r r I - MPL45,MPL45,MPL45V7 1 n 1 4 if 9 -6- MPL-12,MPL-12,MPL-12V1 It X11 7 r':, LI 1 II -3- MPL37,MPL-37, -37AV1 C � 13 I ! 11(5 �i F."! r4 I,��,ar �1 II 1, I $- MPL37,Plan MPL37B,MPL37BVP2V19 p ' 111 r ey �� $ IVPL37,MPL-37, -37V3 «7 11� 1%I � i MPL-06,NPL-06,MPL-06 V1 4E MPL35,Plan MPL-35B,MPL-35Bwp1VO 0 //I !/a _•__ -f- MPL35,MPL-35, f��i7 1, ��' -3- MPL-35,MPL-35APB1,MPL-35APB1V5 ca. /'I%�� 'l; "�'r 7 Ti $ MPL35,MPL35APB2,MPL3.5APB2V3 i / 4,4 $ MPL-35,MPL-35,MPL-35 V6 U) P/ 7.1 /�, !! N / 1 r_�,1,,,..., % II, MPL35,MPL35APB3,MPL-35APB3 V5 C2,7/400. � _y,� • -)(- MPL-09,MPL-09,MPL-09V1 4.,i,:-.U '' A)i.�'_n /,r/r..I -e- NPL-09,NPL-09APBI,MPL-09APB1 V0 O '450 4A -. �1. ! to - NPL-O9,IvPL-09A,MPL-09AV0 ..:,,44,;','..1,2_,:,-. 0 f dsul' /hri' :3- MPL-O02, -02A,NPL-02AV0 EL.? ' !�! -8- NPL-02,MPL-02AP82,MPL-02APB2V0 N e 5410, ` - ----- .4- MPL-0OZ -02AL1,NPL-02AL1 VO U ` ��`; N- MPL-02,MPL-02,MPL-02 V1 fir ... 1 0 -e NPL-02,MPL-02APB1,MPL-02APB1V0 0 2500 5000 7500 10000 12500 -3- MPL-02,MPL-02Al2,NPL-02AL2 V0 -9- MPL-10,MPL-10,MPL-10 V1 Measured Depth(2500 usft/in) $ Plan MPL47,MPL47 (Well tl4),MPL47 wp3 V0 ' IvIrL-34,IVIYL-34,MI-'L-34 V I V 09 June,2015- 17:30 Page 6 of 7 COMPASS • • Hilcorp Energy Company HALLIBURTON Milne Point Anticollision Report for Plan MPL-46-MPL-46 wp3 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor -$...MPL-04,MPL-04,MYL-04 V7 _.. _... I 1 ' - �/J ��5� $ MPL-42,MPL-42,MPL-42 V4 10.00 ��1 ri $ MPL-07,MPL-07,MPL-07 V1 _�-� L',1 t4 -4- MP L-05,MPL-05,MPL-05 V1 2 -�(- MPL-45, - V7 8.75 -6- MPL-12,MPMPLL-4512MPL-4125,' -45 $ MPL-37,MPL-37A,MPL-37AV1 - .A $ MPL-37,PIan MPL-37B,MPL-37BWP2V19 7.50- c n ,1 0- MPL-37,MPL-37,MPL-37 V3 C - ,L $ MPL-06,MPL-06,MPL-06 V1 Lo _ i MPL-35,Plan MPL35B,MPL-35Bwp1 VO 6.25 - - _$r-. MPL-35,MPL-35A,MPL-35AV12 0 �� ` - MPL35,MPL35APB1,MPL-35APB1 V5 LL - , _ $ MPL-35,MPL-35APB2,MPL35APB2 V3 g 5.00 - �- MPL-35,MPL-35,MPL-35 V6 -.775 co f1 ��0, $ MPL-35,MPL-35APB3,MPL-35APB3 V5 • 3.75 -N- M P L-09,MPL-09,MPL-09 V1 03 - 11 li -8- MPL-09,MPL-09APB1,MPL-09APB1 VO - A �'t -J-_, MPL-09,MPL-09A,MPL-09A VO _ F.0 250 iii. •€}- MPL-02,MPL-02A,MPL-02A V0 - -- MPL-02,MPL-02APB2,MPL-02APB2 VO _- Collision Avoidance Req o-Go Zone-Stop Dulling $ MPL-02,MPL-02ALI,MPL-02AL1 VO 1.25-j„...,...---- -- MPL-02,MPL-02,MPL-02 V1 - -lam MPL-02,MPL-02APB1,MPL-02APB1 VO -3- MPL-02,MPL-02AL2,MPL-02AL2 VO 0.00 i i i i i i i a Pill 1 1 1 1 1 1111 i 1 1 1 1 1 1 P 1 1 1 1111 111111 T I T ! Ill ! 1 $ MP L-10,MPL-10,MPL-10 V1 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 -e- Plan MP L-47,MPL-47(Well#4),MP L-47 wp3 VO Measued Depth(2500 usft(in) $ MPL-34,MPL-34,MPL-34 V10 09 June,2015- 17:30 Page 7 o/7 COMPASS • • 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: j?() , L-y c PTD: 9.15-11V Y Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: 11/4- -111! POOL: Ca- Aoni") SC-litk.164r 2kii 01 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements 7 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. 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