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218-106
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Isolate Perforations Hilcorp Alaska 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 12,193'feet 12,057 feet true vertical 10,340 feet 11,554 feet Effective Depth measured 12,193 feet feet true vertical 10,340 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / 13Cr / JFE Bear 11,595' 9,765' 9-5/8" x 7" LTP &1,517 MD Packers and SSSV (type, measured and true vertical depth)(2) 7" X 3.5" PHL See Above TRMAXX SSSV 1,513 TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 5,113, 8,530 & 9,644 WINJ WAG 0 Water-Bbl MD 161' 2,872' 7,503' TVD 0 Oil-Bbl measured true vertical Packer 12,183' Size 6,291, 10,311 & 11,469 N/A Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-106 50-029-22374-01-00 Plugs ADL034633 5. Permit to Drill Number: Endicott Field / Endicott Oil & Seabee Undefined Pool 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-474 0 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 1,300 DIU MPI 2-66A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 1,150 Casing Pressure Tubing Pressure 0 N/A measured Liner Casing Conductor Length 134' 2,845' 7,503' 161' Surface Production 20" 13-3/8" 9-5/8" 7"5,892' 10,330' 4,760psi 10,540psi Burst N/A 5,020psi 6,870psi 10,160psi 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,260psi2,739' 5,933' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 8:34 am, May 17, 2021 Chad Helgeson (1517) 2021.05.17 06:23:09 - 08'00' _____________________________________________________________________________________ Revised By: DG 5/10/2021 SCHEMATIC Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 TD = 12,193’ (MD) / TD = 10,340’(TVD) 20” KB Elev.: 40’/ BF/GL Elev.: 13.3’ 7” 6 12 9-5/8” 1 2 15 Min ID=2.75” @ 11,554’ PBTD =12,057’ (MD) / PBTD =10,208’(TVD) 3 13- 10 4& 5 14 9-5/8” Window: 7,503’ MD 16 7 9 8 11 13 7” Stage Tool @ 10,542’ MD Stuck IBP at 10,340’ MD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 161’ N/A 13-3/8” Surface 68/ N-80/ Btrs 12.415 Surface 2,872’ 0.150 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 7,503’ 0.0732 7" Liner 26 / L-80 / DWC 6.184 6,291’ 12,183’ 0.0372 TUBING DETAIL 3-1/2" Tubing 9.3/ 13Cr / JFE Bear 2.992 Surface 11,595 0.0087 JEWELRY DETAIL No Depth Item 1 1,517’ 3.5” SLB - TRMAXX SSSV w/ X-Nipple - ID= 2.813” GLM DETAIL: SLB - SPM-1-1/2” w/ RK Latch 24,095’STA 6: Patco - Dev= , VLV= LGLV, Port= 16/64, TVD= 3698’, Date=12/3/2018 36,970’STA 5: Patco - Dev= , VLV= LGLV, Port= 16/64, TVD= 5566’, Date=12/3/2018 4 6,291’ 9-5/8”x7” Liner Top Packer 5 6,306’ 9-5/8”x7” Liner Hanger 68,294’STA 4: Patco - Dev= , VLV= DGLV, Port= 0, TVD= 6588’, Date=12/3/2018 79,088’STA 3: Patco - Dev= , VLV= LGLV, Port= 16/64, TVD= 7349’, Date=12/3/2018 89,888’STA 2: Patco - Dev= , VLV= DMY, Port= 0, TVD= 8122’, Date= 9 10,191’STA 1: Patco - Dev= , VLV= OGLV, Port= 22/64, TVD= 8415’, Date=12/3/2018 10 10,270’ 3-1/2” HES - X Nipple – ID= 2.813” 11 10,311’ 7” x 3-1/2” HES PHL Packer 12 10,363’ 3-1/2” Sliding Sleeve XD – Down to Open (ID=2.813”) – Closed 11/03/2020 13 11,469’ 7” x 3-1/2” HES PHL Packer 14 11,514’ 3-1/2” HES - X Nipple – ID 2.813” 15 11,554’ 3-1/2” HES - XN Nipple – ID= 2.75” 16 11,594’ 3-1/2” WLEG – ID= 2.992” – Btm @ 11,595’ PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Fenris 10,395’ 10,405’ 8,610’ 8,620’ 10’ 10/3/18 Shut (SSD) 3-3/8” FIV 11,842’ 11,858’ 10,002’ 10,017’ 16’ 12/30/18 Open 2-3/8” FIV 11,842’ 11,858’ 10,002’ 10,017’ 16’ 06/21/19 Open 2-3/8” FIV 11,892’ 11,902’ 10,050’ 10,060’ 10’ 06/21/19 Open 2-3/8” FIV 11,905’ 11,931’ 10,062’ 10,087’ 26’ 10/29/18 Open 2-3/8” FIV 11,905’ 11,931’ 10,062’ 10,087’ 26’ 06/21/19 Open 2-3/8” FIV 11,952’ 11,962’ 10,106’ 10,115’ 10’ 7/14/19 Open 2-3/8” Reference Perf Log: HES MWD OPEN HOLE / CEMENT DETAIL 13-3/8” 4,557 cu/ft Permafrost in 17.5” Hole 9-5/8" 575 cu/ft Class ‘G’ in a 12-1/4” Hole 7”Stg 1 126 sx of 14.5 ppg Class G – 30 BBLS Stg 2 111 sx of 15.8 ppg Class G – 23 BBLS WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,458’ Angle at Top Perf = 15 Deg. @ 10,395’ TREE & WELLHEAD Tree 4-1/16” CIW Wellhead CIW GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion - 10/1/1983 Perf Add – 7/14/2019 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well has a SSSV Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A E-Line 50-029-22374-01-00 218-106 11/30/2020 4/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary PT PCE 250L/3500H. RAN 2.60" B. GUIDE & 1.90" BLIND BOX TO IBP 3 TIMES, JARRED DOWN TOTAL OF 2 HR 15 MIN…LAST TAG @ 11,517' SLM. RAN SPEAR TO 11,527' SLM IN ATTEMPT TO PUNCTURE INFLATABLE BAG. UNSURE IF PUNCTURED DUE TO NO PRESSURE CHANGE. WELL LEFT S/IRED. WELL S/I ON ARRIVAL, PT PCE 250L/3500H. RAN 2.60" B. GUIDE & 1.90" BLIND BOX TO IBP @ 11,446' SLM, JARRED DOWN AGGRESSIVELY & PUSHED IBP TO 11,511' SLM. CONT. ON 12/01/20 WSR, WELL LEFT S/I. 12/1/2020 - Tuesday 11/29/2020 - Sunday WELL S/I UPON ARRIVAL. Stab onto well for pressure test: low 300psi, high 3500psi. PERFORM GAMMA/CCL JEWELRY LOG FROM 11,416' - 11,990'. ATTEMPT TO SET BAKER 2.5" IBP @ 11498' MD, SETTING TOOL FAILED DURING SETTING, LEFT TOOL IN TUBING @ ~11470'. TOOLS LEFT IN HOLE: BAKER HYDRUALIC SETTING TOOL, 2-1/2" PERMANENT INFLATABLE BRIDGE PLUG (OAL=13.24', MAX OD=2.5). 11/30/2020 - Monday 12/2/2020 - Wednesday PT 250L/3,500H. RAN 2.60" B. GUIDE & 2" RB TO IBP @ 11,492' SLM, MOVED IBP UP HOLE TO 11,384' SLM. SHEARD OFF AS OBJECTIVE IS TO PUSH DOWN. RAN 2.35" BLIND BOX TO IBP @ 11,377' SLM, JARRED FOR 45 MIN & MOVED IBP TO 11,382' SLM. PAD-OP FLOWED WELL FOR ~10-15 MIN, IBP MOVED UP HOLE TO 10,342' SLM (POSSIBLY SLIDING SLEEVE). RAN 2.60" B. GUIDE & 2" SB TO IBP @ 10,342' SLM, JAR 1 HR 20 MIN @ 1700-1900#, NO MOVEMENT. WELL LEFT S/I. 12/3/2020 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/3,500H. RUN 2" SB PULLING TOOL (1/2 brass), 2.70" BELL GUIDE TO IBP @ 10,339' SLM, UNABLE TO LATCH, PULLING TOOLS SHEARED. 12/4/2020 - Friday Standby due to wind. 12/5/2020 - Saturday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/3,500H. RUN 2" SB PULLING TOOL (brass), 2.70" BELL GUIDE TO IBP @ 10,341' SLM, UNABLE TO LATCH, PULLING TOOLS SHEARED. RUN 2" RB PULLING TOOL (steel), 2.70" BELL GUIDE TO IBP @ 10,341' SLM, RECOVER TOP F/N OF IBP (swivel off). HOT SHOT TO PRUDHOE TO P/U OVERSHOT. 12/6/2020 - Sunday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/3,500H. PRESSURE TBG UP TO 1,600psi. RUN 2.60" DECENTRALIZER, 2.50" CLOCK, XO, 2.70" CENT, 0.63" SPEAR (oal=81"), S/D @ 10346' SLM, NO MARKS OR PRESSURE CHANGE. RUN W/ 2.60" DECENTRALIZER, 2.50" CLOCK, 2.50" MODIFIED BAILER CUT AT AN ANGLE TO A POINT, S/D ON TOP OF IBP @ 10,341' SLM. RUN SAME SETUP BESIDE IBP TO 10,346' SLM, JAR DOWN FOR 10min, HAVE TO HIT SEVERAL. OJ LICKS TO COME FREE, NO PRESURE CHANGE, METAL MARKS @ TOP OF CUT BAILER. Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A E-Line 50-029-22374-01-00 218-106 11/30/2020 4/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary 12/7/2020 - Monday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/3,500H. MAKE TWO RUNS W/ 2.60" DECENTRALIZER, 2.50" CLOCK, 2.50" MODIFIED BAILER CUT. AT A STEEP ANGLE TO A POINT (add serations to edge on second run) TO 10,346' SLM. MAKE TWO RUNS W/ 2.60" DECENTRALIZER, XO, 2.70" CENT, 0.63" SPEAR (oal=81" & cut btm to a center point for second run) TO 10,345' SLM, UNABLE TO WORK DEEPER, NO PRESSURE CHANGE. CUT 100' OF WIRE & RETIE. 12/8/2020 - Tuesday PT PCE 250L/3,500H. Rih and recover 3' of the IBP. Continue fishing operations. 12/10/2020 - Thursday BRAIDED LINE JOB, WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/ 3,500H. RUN 2-7/8" GS PULLING TOOL & LATCH 2.65" OVERSHOT / IBP @ 10,341' SLM, HIT OJ LICKS @ 3,950# FOR 3hrs, IBP MOVE UP TO 10,332' SLM. 12/11/2020 - Friday BRAIDED LINE JOB, S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/ 3,500H. ATTEMPT TO BLEED TBG DOWN TO 300psi, NO MOVEMENT OF IBP, PRESSURE TBG UP TO 1,200psi. MAKE SEVERAL RUNS W/ 2-7/8" GS PULLING TOOL & LATCH 2.65" OVERSHOT / IBP. @ 10,345' SLM, HIT OJ LICKS @ 3,950# FOR 3+hrs, IBP MOVE UP TO 10,343' SLM. 12/12/2020 - Saturday STANDBY TO R/D BRAIDED LINE & SWAP TO SLICKLINE, TRAVEL TO MILNE PT. 1/24/2021 - Sunday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/2,500H. PRESSURE TBG UP TO 1,300psi, FIND HYDRATES @ 2,459' SLM. RUN 3-1/2" BAIT SUB, 1.25" SPEAR (12 BARBS), S/D & LATCH IBP FISH @ 10,345' SLM, HIT 3 OJ LICKS @ 1,600#, TOOLS SLIP OFF. 1/19/2021 - Tuesday WELL S/I ON ARRIVAL. BRAIDED LINE JOB, S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT, PT PCE 250L/2,000H. RAN 2-7/8" PRGS TO FISH @ 10,316' SLM, JAR FOR 5 HOURS @ 9,000#. 1/21/2021 - Thursday BRAIDED LINE JOB, S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT, PT PCE 250L/2,000H. RAN 2-7/8" PRGS TO FISH @ 10,315' SLM, JAR FOR 8 HOURS @ 8,500# (13 hours total), POOH w/ OVERSHOT & INNER MANDREL OF IBP. JOB INCOMPLETE, PART OF FISH STILL IN HOLE, WELL LEFT S/I. Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A E-Line 50-029-22374-01-00 218-106 11/30/2020 4/19/2021 Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/2,500H. MAKE SEVERAL RUNS W/ 2 & 3 PRONG WIRE GRABS & SPEAR TO FISH IBP PIECES @ 10,345' SLM, RECOVER 7" CHUNK OF RUBBER & FIVE METAL BAND PIECES (RANGING FROM 8" TO 32"), SEE JOB LOG. HANG UP IN SSSV NIPPLE @ 1,499' SLM, RUN 3-1/2" BLB TO WORK PAST & CLEAN UP NIPPLE FROM POSSIBLE PIECES. 1/25/2021 - Monday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/2500H. RUN 2.70" LIB & S/D @ 1,498' SLM, RECOVER IMPRESSION OF WAVY OBJECT ABOUT 2/3 ACROSS TBG. MAKE SEVERAL RUNS W/ 3 PRONG WIRE GRABS & SPEAR TO REMOVE POSSIBLE OBSTRUCTION FROM SSSV, SEE JOB LOG. RUN 2.85" NO-GO CENT TO 1,499' SLM, RUN FLAPPER CHECKER & S/D HIGH @ 1,497' SLM, FLAPPER NOT THE ISSUE. RUN 3-1/2" BLB & 2.80" GAUGE RING, S/D @ 1,499' SLM, WORK UP AND DOWN FOR 15min, DRIFT TBG TO 1,550' SLM PAST RS. RUN 2.70" LIB, DRIFT THROUGHT SSSV FREELY, DRIFT TBG & S/D @ 10,344' SLM, HAVE IMPRESSION OF POSSIBLE BANDS LAYING ON LOW SIDE. 1/26/2021 - Tuesday WELL S/I ON ARRIVAL, NOTIFY PAD-OP TO FILL OUT PERMIT & WELL RELEASE FORM, PT PCE 250L/2500H. MAKE SEVERAL RUNS W/ 2 & 3 PRONG WIRE GRABS & SPEAR TO FISH IBP PIECES @ 10345' SLM, RECOVER 7". CHUNK OF RUBBER & FIVE METAL BAND PIECES (RANGING FROM 8" TO 32"), SEE JOB LOG. HANG UP IN SSSV NIPPLE @ 1,499' SLM, RUN 3-1/2" BLB TO WORK PAST & CLEAN UP NIPPLE FROM POSSIBLE PIECES. 1/27/2021 - Wednesday (T/I/O = 1500/1600/0) Shot a fluid level = 7 seconds. Jumpered gas from AL to tubing. Pressure on tubing increased 100 psi in one hour. Shot fluid level, same depth. Put well on gaslift. (Final T/I/O = 1600/1600/0). 1/30/2021 - Saturday WELL SHUT-IN ON ARRIVAL. PT PCE 250L / 3,500H. RAN BAITED 3-PRONG WIRE TO 10,340' SLM…RECOVERED 4" OF BROKEN IBP BAND. RAN BAITED SPEAR TO 10,340' SLM. RECOVERED 3" OF BROKEN IBP BAND. 1/31/2021 - Sunday CONTINUE FROM 1-30-21 WSR, PT PCE 250L / 3,500H. RAN BAITED 3-PRONG WIRE TO 10,340' SLM…RECOVERED 2-1/2' OF BROKEN IBP BAND. RAN BAITED SPEAR TO 10,340' SLM. RECOVERED 5" OF BROKEN IBP BAND. 2/19/2021 - Sunday 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Set Bridge Plug w/ Cement Cap Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Isolate Perforations 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,193'11,554' Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Liner 10,540psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7,503' Perforation Depth MD (ft): See Schematic Endicott Field / Endicott Oil & Seabee Undefined Pool DIU MPI 2-66A 20 AAC 25.055 9-5/8" x 7" LTP & (2) 7" X 3.5" PHL and TRMAXX SSSV Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 12,183' 134' 20" 13-3/8"2,845' 9-5/8"7,503'6,870psi 5,020psi2,739' 5,933' 2,872' See Schematic 7"5,892' 10,330' 3-1/2" 12,057' 161' 161' 9.3# / 13Cr / JFE Bear TVD Burst 11,595 10,160psi MD N/A 218-106 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22374-01-00 Hilcorp Alaska LLC Length Size 10,340' 12,193' 10,340'3,168 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL034633 6,291MD/ 5,2113TVD, 10,311MD/ 8,530TVD & 11,469MD/ 9,644ZTVD and 1,517MD/ 1,513TVD dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Authorized Signature: 11/20/2020 No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:38 am, Nov 09, 2020 320-474 Chad A Helgeson 2020.11.06 15:02:30 -09'00' DSR-11/10/2020 X DLB 11/09/2020 10-404 MGR09NOV2020Comm. 10/12/2020 dts 11/12/2020 JLC 11/12/2020 RBDMS HEW 11/12/2020 SBHPS Well: END 2-66A PTD: 218-106 API: 50-029-22374-01 Well Name:END 2-66A API Number:50-029-22374-01 Current Status:SI Rig:E-Line Estimated Start Date:Nov 20, 2020 Estimated Duration:1day Reg.Approval Req’std?NA Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:218-081 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer: AFE Number: WellEZ Entry Required?No Current Bottom Hole Pressure:4,168 psi @ 10,000’ ss TVD (Based on SBHP 11/1/2020) Maximum Expected BHP:4,168 psi @ 10,000’ ss TVD Max. Anticipated Surface Pressure:3,168 psi (Based on 0.1 psi/ft. gas gradient) Min ID:2.75” ID, 3-1/2” XN Nipple at 11,554’ MD Brief Well Summary: The END 2-66A was completed/sidetracked in Dec 2018. A deep gaslift design was installed but the well has experienced inconsistent production/slugging despite effective gas lift. Subsequent trips in the well have encountered an abnormally high level of paraffin/asphaltenes obstructing tubing. Perfs were added in the summer of 2019 to help increase production fluid temps and reduce paraffin issues. The well watered out and was SI. Objective: RIH on E-line with an inflatable bridge plug. Set the plug at ±11,950’ MD to isolate the perforations at 11,952’- 11,962’ MD. Dump bail 10’ of CMT on top of the IBP. Procedure: Slickline 1. MIRU E-line Unit 2. Pressure test to 250psi low/3500psi high. 3. PU, RIH with Inflatable Bridge Plug. 4. Set the IBP at ±11,950’ MD. 5. POOH 6. RIH with E-line CMT bailer, Dump Bail 10’ of CMT on top of the IBP. 7. POOH 8. RD E-line Unit Attachments: Proposed Wellbore Schematic 218-106 SFD 11/10/2020 _____________________________________________________________________________________ Revised By: DWG 11/6/2020 SCHEMATIC Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 TD =12,193’ (MD) / TD = 10,340’(TVD) 20” KB Elev.: 40’/ BF/GL Elev.: 13.3’ 7” 6 12 9-5/8” 1 2 15 Min ID=2.75” @ 11,554’ PBTD =12,057’ (MD) / PBTD =10,208’(TVD) 3 13-3/8 ” 10 4& 5 14 9-5/8” Window: 7,503’ MD 16 7 9 8 11 13 7” Stage Tool @ 10,542’ MD IBP Top- ±11,950’ MD TOC – ±11,940’ MD 17 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 161’ N/A 13-3/8” Surface 68/ N-80/ Btrs 12.415 Surface 2,872’ 0.150 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 7,503’ 0.0732 7" Liner 26 / L-80 / DWC 6.184 6,291’ 12,183’ 0.0372 TUBING DETAIL 3-1/2" Tubing 9.3/ 13Cr / JFE Bear 2.992 Surface 11,595 0.0087 JEWELRY DETAIL No Depth Item 1 1,517’ 3.5” SLB - TRMAXX SSSV w/ X-Nipple - ID= 2.813” GLM DETAIL: SLB - SPM-1-1/2” w/ RK Latch 24,095’STA 6: Patco - Dev= , VLV= LGLV, Port= 16/64, TVD= 3698’, Date=12/3/2018 36,970’STA 5: Patco - Dev= , VLV= LGLV, Port= 16/64, TVD= 5566’, Date=12/3/2018 4 6,291’ 9-5/8”x7” Liner Top Packer 5 6,306’ 9-5/8”x7” Liner Hanger 68,294’STA 4: Patco - Dev= , VLV= DGLV, Port= 0, TVD= 6588’, Date=12/3/2018 79,088’STA 3: Patco - Dev= , VLV= LGLV, Port= 16/64, TVD= 7349’, Date=12/3/2018 89,888’STA 2: Patco - Dev= , VLV= DMY, Port= 0, TVD= 8122’, Date= 9 10,191’STA 1: Patco - Dev= , VLV= OGLV, Port= 22/64, TVD= 8415’, Date=12/3/2018 10 10,270’ 3-1/2” HES - X Nipple – ID= 2.813” 11 10,311’ 7” x 3-1/2” HES PHL Packer 12 10,363’ 3-1/2” Sliding Sleeve XD – Down to Open (ID=2.813”) – Closed 11/03/2020 13 11,469’ 7” x 3-1/2” HES PHL Packer 14 11,514’ 3-1/2” HES - X Nipple – ID 2.813” 15 11,554’ 3-1/2” HES - XN Nipple – ID= 2.75” 16 11,594’ 3-1/2” WLEG – ID= 2.992” – Btm @ 11,595’ 17 ±11,950’ Inflatable Bridge Plug w/ 10’ of CMT PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Fenris 10,395’ 10,405’ 8,610’ 8,620’ 10’ 10/3/18 Shut (SSD) 3-3/8” FIV 11,842’ 11,858’ 10,002’ 10,017’ 16’ 12/30/18 Open 2-3/8” FIV 11,842’ 11,858’ 10,002’ 10,017’ 16’ 06/21/19 Open 2-3/8” FIV 11,892’ 11,902’ 10,050’ 10,060’ 10’ 06/21/19 Open 2-3/8” FIV 11,905’ 11,931’ 10,062’ 10,087’ 26’ 10/29/18 Open 2-3/8” FIV 11,905’ 11,931’ 10,062’ 10,087’ 26’ 06/21/19 Open 2-3/8” FIV 11,952’ 11,962’ 10,106’ 10,115’ 10’ 7/14/19 Open 2-3/8” Reference Perf Log: HES MWD OPEN HOLE / CEMENT DETAIL 13-3/8” 4,557 cu/ft Permafrost in 17.5” Hole 9-5/8" 575 cu/ft Class ‘G’ in a 12-1/4” Hole 7”Stg 1 126 sx of 14.5 ppg Class G – 30 BBLS Stg 2 111 sx of 15.8 ppg Class G – 23 BBLS WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,458’ Angle at Top Perf = 15 Deg. @ 10,395’ TREE & WELLHEAD Tree 4-1/16” CIW Wellhead CIW GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion - 10/1/1983 Perf Add – 7/14/2019 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well has a SSSV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AIJ6 b 1 2019 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing shutdown Ll Performed: Suspend ❑ Perforate ❑✓ ,operations Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Po❑ RepairWell[-] Re-enter Susp Well ❑ Other: ❑ 2. Operator 14. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Stratigraphic ❑ Exploratory ❑ Service ❑ 218-106 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 6. API Number: 99503 50-029-22374-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL034633 DIU MPI 2-66A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Endicott Field / Endicott Oil & Seabee Undefined Pool 11. Present Well Condition Summary: Total Depth measured 12,193 feet Plugs measured 12,057 feet true vertical 10,340 feet Junk measured 11,554 feet 6,291, 10,311 & Effective Depth measured 12,193 feet Packer measured 11,469 feet 5,113, 8,530 & true vertical 10,340 feet true vertical 9,644 feet Casing Length Size MD TVD Burst Collapse Conductor 134' 20" 161' 161' N/A N/A Surface 2,845' 13-3/8" 2,872' 2,739' 5,020psi 2,260psi Production 7,503' 9-5/8" 7,503' 5,933' 6,870psi 4,760psi Liner 5,892' 7" 12,183' 10,330' 10,160psi 10,540psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feel Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / 13Cr / JFE Bear 11,595' 9,765' 9-5/8" x 7" LTP 1,517 MD Packers and SSSV (type, measured and true vertical depth) (2) 7"X 3.5" PHL See Above TRMAXX SSSV 1,513 TVD 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: 74 0 451 1,250 269 Subsequent to operation:]51 0 1 1,659 1,550 277 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 WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C, 0. Exempt: 319-288 Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wriyard0hilcorp.com Authorized Signature: Date 7/30/2019 Contact Phone. 777-8547 Form 10-404 Revised 4/2017 R MS-9"AUG 0 12019 Submit Original Only K corn Alaska. J.T.C. KB Bev.: 40'/ BF/GL Elev.: 13.3' TD=12,193' (ND) /TD=10,34f7(TVD) PBfD= ]2,057 (ND) / PBTD=10,208'(7VD) SCHEMATIC Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD H2S Readings Average 230 -260 PPM on A/L & Gas Injectors Tree 4-1/16" CIW Well has a SSSV Wellhead CIW OPEN HOLE / CEMENTDETAIL 13-3/8" 4,557 cu/ft Permafrost in 17.5" Hole 9-5/8" 575 cu/ft Class'G' Ina 12-1/4" Hole 7„ Stg 1126 sx of 14.5 ppg Class G-30 BBLS Stg 2 111 sx of 15.8 ppg Class G -23 BBLS CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A / N/A N/A Surface 161' N/A 13-3/8" Surface 68/ N-80/ Btrs 12.415 Surface 2,872' 0.150 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 7,503' 0.0732 7" Liner 26/L-80/DWC 6.184 6,291' 12,183' 0.0372 TUBING DETAIL 3-1/2" Tubing 9.3/13Cr/JFE Bear 1 2.992 1 Surface 11,5950.0087 WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,458' Angle at Top Perf =15 Deg. @ 10,395' JEWELRY DETAIL No Depth Item 1 1 1,517' 3.5" SLB -TRMAXXSSSVw/X-Nipple-ID=2.813" Date Status GLM DETAIL: SLB - SPM -1-1/2" w/ RK Latch 2 4,095' STA 6: Patco - Dev=, VLV= LGLV, Port= 16/64, ND= 3698', Date=12/3/2018 3 6,974 STA 5: Patco - Dev=, VLV= LGLV, Port= 16/64, ND= 5566', Date=12/3/2018 4 6,291' 9-5/8"x7" Liner Top Packer 5 6,306' 9-5/8"x7" Liner Hanger 6 8,294' STA 4: Patco - Dev--, VLV= DGLV, Port= 0, ND= 6588', Date=12/3/2018 7 9,088' STA 3: Patco - Dev=, VLV= LGLV, Port=16/64, ND= 7349', Date=12/3/2018 8 9,888' STA 2: Patco - Dev=, VLV= DMY, Port= 0, TVD= 8122', Date= 9 10,191' STA 1: Patco- Dev=, VLV= DGLV, Port= 22/64, TVD= 8415', Date=12/3/2018 30 10,270' 3-1/2"HES -X Nipple - ID= 2.813" 11 10,311' 7" x 3-1/2" HES PHL Packer 12 10,363' 3-1/2" Sliding Sleeve XD -Down to Open 1D=2.813") -Closed 10/15/2018 13 11,469' 7"x3-1/2"HES PHL Packer 14 11,514' 3-1/2" HES- X Nipple -ID 2.813" 15 11,554' 3-1/2"HES -XN Nipple - ID= 2.75" 16 11,594' 3-1/2" WLEG - ID= 2.992" - Btm @ 11,595' PERFORATION DETAIL :NDSands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Ferris 10,395' 10,405' 8,610' 8,620' 10' 10/3/18 Shut (SSD) 3-3/8" FIV 11,842' 11,858' 10,002' 10,017' 16' 12/30/18 Open 2-3/8" FIV 11,842' 11,858' 10,002' 10,017' 16' 06/21/19 Open 2-3/8" FIV 11,892' 11,902' 10,050' 10,060' 10' 06/21/19 Open 2-3/8" FIV 11,905' 11,931' 10,062' 10,087' 26' 10/29/18 Open 2 -3/8 - FIV 11,905' 11,931' 10,062' 10,087' 26' 06/21/19 Open 2-3/8" FIV 11,952' 11,962' 10,106' 10,115' 10' 7/14/19 Open 2-3/8" Reference Perf Log: HES MWD GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion -10/1/1983 Perf Add -7/14/2019 Revised By: TDF 7/29/2019 7111111111111111 IIIIIIIIIIIN Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date END 2-66A Slick Line 50-029-22374-01-00 218-106 1 6/21/2019 1 7/14/2019 Daily Operations. 6/19/2019- Wednesday No operations to report. 6/20/2019-Thursday Well Shut-in on arrival (SLB E-line Perforating). Rig up, pt lubricator to 300/3,100 PSI. Gun 1, Perforated Interval = 11,905' - 11,931', CCL to Top Shot =12.5', CCL Stop Depth = 11,892.5'. Gun 2, Perforated Interval = 11,892' -11,902'. CCL to Top Shot = 7.5', CCL Stop Depth =11,884.5'. Gun 3 Perforated Interval =11,842' -11,858'. CCL to Top Shot = 7.5', CCL Stop Depth = 11,834.5'. All passes correlated to Halliburton MWD Log. dated 26-Sep-2018. Job Complete, well left shut-in on departure. 6/21/2019 - Friday No operations to report. 6/22/2019 -Saturday No operations to report. 6/23/2019-Sunday No operations to report. 6/24/2019 - Monday No operations to report. 6/25/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A Slick Line 50-029-22374-01-00 218-106 6/21/2019 7/14/2019 Daily Operations. 7/3/2019 - Wednesday No operations to report. 7/4/2019 - Thursday No operations to report. 7/5/2019 - Friday WELL FLOWING ON ARRIVAL. T/I/O = 1,050/950/450. SI T/I/O = 1,280/1250/150. PT LUBE TO 2,800 PSI. RIH W/ 5' OF PERF GUNS AND SAT DOWN AT 4,400' AND WORKED DOWN TO 4,570'. HAD TO PULL TO MAX SAFE PULL TO COME FREE & PULLED HEAVIER ALL THE WAY TO SURFACE. GUN LAYERED IN PARAFFIN. RDMO. 7/6/2019 -Saturday No operations to report. 7/7/2019 - Sunday No operations to report. 7/8/2019 - Monday No operations to report. 7/9/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well NameRig API Number Well Permit Number Start Date End Date END Slick Line 50-029-22374-01-00 218-106 6/21/2019 7/142019 Daily Operatioons.ns. 7/10/2019- Wednesday No operations to report. 7/11/2019-Thursday WELL FLOWING UPON ARRVAL, NOTIFY PAD-OP, 5/1 WELL, PT PCE 250L/2,800H. RUN 3-1/2" BLB, 2.80" GAUGE RING, BRUSH & FLUSH TBG TO XN-NIPPLE @ 11,521' SLM / 11,554' MD. LRS ONLINE PUMP 113 BBLs OF HOT DIESEL DOWN TBG @ 1BBL A MIN. DRIFTTBG WITH 10'x 2.70" DUMMY WHIPSTOCK & TAG TD @ 11,986' SLM / 12,019' MD, 1,150# P/U OFF BTM. JOB COMPLETE, PAD-OP NOTIFIED TO LEAVE WELL S/I UPON. 7/12/2019 - Friday No operations to report. 7/13/2019-Saturday No operations to report. 7/14/2019-Sunday Well Shut-in on Arrival (SLB E-line Perforating). Rig up, PT Lubricator to 250/3,200 PSI. Perforate 2 Intervals (10') with 2-3/8" Geodynamic Razor, 6 spf, 60 deg phase. Gun# 1 PERF (5) INTERVAL @ 11,957'- 11,962'(CCL to Top Shot = 3.5', CCL Stop Depth =11,953.5"). PSI CHANGED ON TBG FROM 475# TO 700# AFTER PERF'D). Gun# 2 PERF (5') INTERVAL @ 11,952' - 11957' (CCL to Top Shot = 3.5', CCL Stop Depth =11,948.5'). NO CHANGE IN PSI. Job Complete, well put back on production upon departure. 7/15/2019 - Monday No operations to report. 7/16/2019 -Tuesday No operations to report. Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 xil'n*p nl;.rla, LM Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 07/18/2019 To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 JENDICOTT MPI 2-66A (PTD 218-106) CD 1: Flilcorp_ AP12-BEA_Perf 211un19_FlNAL CD 2: Flilcorp_N-IP1-2-66A Per€ 14Jul19_FINAL Please acknowledge 3 102 1 31022 pt by sigping and return RECEIVED JUL 19 2019 AOGCC copy of this transmittal or FAX to 907 777.8337 Received By/ ,/I ///J// ) // // / ,r Date: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager 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 vvvvv.a ogc c.alaska.gov Re: Endicott Field, Endicott Oil and Seabee Undefined Pool, DIU MPI 2-66A Permit to Drill Number: 218-106 Sundry Number: 319-288 Dear Mr. Helgeson: 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, essi�n �A ielowski Commissioner DATED this 12 day of June, 2019. RBDMS± JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECENED JUN 0 7 2019 9)`1:s c- 117, t 17 A I-% 1--� r� r"' 1. Type of Request: Abandon El Plug Perforations Fracture StimulateEl Repair Well El I- ' '6FZratio'ns �—hutdown [I Suspend 11 Perforate Other Stimulate E] Pull Tubing 11 Change Approved ProgramEl Plug for Redrill 0 Perforate New Pool El Re-enter Susp Well El Alter Casing 1-1 Other: ESP Change -out El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory Development Stratigraphic Service 218-106 _ 3. Address: 3800 Conterpoint Dr, Suite 1400 6. API Number Anchorage Alaska 99503 50-029-22374-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 DIU MPI 2-66A Will planned perforations require a spacing exception? Yes El No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL034633 ' I Endicott Field Endicott Oil & Seabee Undefined Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft: Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,19Y 10.340' 12,193' 10,3401 279U 12,057' NIA Casing Length Size MD TVD Burst Collapse Conductor 134' 20" 161, 161, NIA N/A Surface 2,845' 13-3/8" 2,872' 2,739' 5,020psi 2,260psi Production 7,503- 9-5/81, 7,503' 5,933' 6,870psi 4,760psi Liner 5,892' 7" 1 12,183- 10,330' 1 1011160psi 10,540psi Perforation Depth MD (ft): Perforation Depth TVD (ft: Tubing Size: Tubing Grade: Tubing MO (ft): See Schema See Scl� 3-1/2" 9.3# 13Cr I JFE Bear 11,595 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 6,291MD/ 5,2113TVD, 10,31 1MD/ 8,530TVD & 11,469MD/ 9,644TVD 9-5/8'x 7' LTP & (2) 7"X 3.5" PHIL and TRMAXX SSSV and 1,517MD/ 1,513TVD 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch El Exploratory 11 Stratigraphic Development Service 14. Estimated Datefo 15. Well Status after proposed work: Commencing Operations: 6/2112019 OIL [2] WINJ F] WDSPL E] Suspended El GAS WAG GSTOR SPLUG El 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. ILK, (01211 Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title, Operations Manager Contact Email: wrivardidlhilCorl).COM Contact Phone, 777-8547 Authorized Signature: YeW14 Date 6/7/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity SOP Test Mechanical Integrity Test Location Clearance Other Post Initial Injection MIT Req'd? Yes 0 No 71 RBDMS!:t/ JUN 13 2019 Spacing Exception Required? Yes 11 No i/ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 0- ORIGINAL ,e el/40i Submit Form and Form 10-403 Revised 60%17 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate -Mf 161KIP? K lfit o n Alk.. LU Perforations Well: END 2-66A PTD:2181060 API: 50-029-22374-01-00 Well Name: END 2-66A API Number: 50-029-22374-01-00 Current Status: Online Rig: EL Estimated Start Date: June 21, 2019 Estimated Duration: 3 days Reg.Approval Req'std? NA Date Reg. Approval Rec'vd: NA Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 2181060 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: Well EZ Costs Required: Yes Current Bottom Hole Pressure: Maximum Expected BHP: Max. Anticipated Surface Pressure: Last SI WHIP: Min ID: Reference Log: Brief Well Summary: 3790psi @ 10,000' TVD (Based on SBHPS Taken on 5/14/19) 3790psi @ 10,000' TVD (Based on SBHPS Taken on 5/14/19) 2790 psi (Based on 0.1 psi/ft. gas gradient) 2000 psi (Taken on 05/14/19) 2.75" ID 3-1/2" XN at 11,554' MD HES ROP DGR MWD Log Dated 26 -Sep -18 (Plot Date 30 -Sep -18) END 2-66A was completed and perforated in the Kekiktuk FIV in October 2018. The well came on at a competitive water cut but fluid level quickly fell off by half and the well experienced issues flowing. Follow-up diagnostics indicated higher than normal levels of asphaltenes in the tubing. Subsequent tubing treatments of xylene appeared to clear up asphaltenes in the tubing but fluid rates never restored. It is assumed that some damage has occurred at the perforations and that reperforating may restore productivity. Pending reperf results, additional perfs may be added in the FIV to increase fluid rate. Objective: Using Eline, re -perforate and add perforations to the following Kekiktuk FIV intervals for increased oil production. Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 2,800psi high. 2. MU perforating tool string with 2 to 2-3/8", 5-6spf, 60 deg phasing guns with deep penetrating charges. 3. RIH and correlate 1't gun run to reference log HES ROP DGR MWD Log Dated 26 -Sep -18 Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to perforating for final approval of tie in. Gun Run # Perf Top Perf Bottom Perf Length 1 (Re-Perf) ±11,905' ±11,931' 26' 2 (Add-Perf) ±11,892' ±11,902' 10' 3 (Re-Perf) ±11,842' ±11,858' 16' Total 52' Table 1: END 2-66A Proposed Gun Runs Confirm with respect to signed Final Approved Perforation Request Form 4. Perforate V gun run as per Table 1: END 2-66A Proposed Gun Runs. POOH. a. Note any tubing pressure change in WSR. 5. Repeat steps 2-4 for gun runs 2 & 3 as per Table 1: END 2-66A Proposed Gun Runs. 6. RD Eline. Perforations Well: END 2-66A PTD:2181060 l il.,p Alaska. LD API: 50-029-22374-01-00 Oepratlons 7. Bring well back on production for -2 weeks. Obtain minimum of two well tests. If there is insufficient improvement in overall fluid rates, proceed with contingent add perfs. Contingent Eline Add Perforations 8. RU EL unit and pressure test to 250psi low 2,800psi high. 9. MU perforating tool string with 2 to 2-3/8", 5-6spf, 60 deg phasing gun with deep penetrating charges. 10. RIH and correlate to reference log HES ROP DGR MWD Log Dated 26 -Sep -18 Contact OE Wyatt Rivard 1(509) 670-8001 or Taylor Wellman at 1(907) 947-9533 prior to perforating for final approval of tie in. 11. Perforate from ±11,950' to ±11,960' as per signed Final Approved Perforations Request Form a. Note any tubing pressure change in WSR. 12. Repeat steps 2-4 for gun run 2 as per Table 2: END 2-66A Contingent Add Perf Gun Runs. 13. RD Eline. Attachments: Proposed Well Schematic K E ilkwrP Alaska. LLC KB Bev.: 40/ BF/GL Elev.: 13.3' PROPOSED SCHEMATIC TD =12,193' (NV)/TD= 10,34U(M) PBTD=12,051IND) / PBID=10,2W'(W) Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD H25 Readings Average 230 -260 PPM on A/L & Gas Injectors Tree 4-1/16" OW Well has a SSSV I I Wellhead I OW OPEN HOLE / CEMENT DETAIL 13-3/8" 4,557 cu/ft Permafrost in 17.5" Hole 9-5/8" li 575 cu/ft Class'G' in a 12-1/4" Hole 7" Stg 3126 sx of 14.5 ppg Class G-30 BELS Stg 2111 sx of 15.8 ppg Class G -23 BBIS CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 161' N/A 13-3/8" Surface 68/N-80/Btrs 12.415 Surface 2,872' 0.150 9-5/8" Production 47 / NT805 / NSCC 8.681 Surface 7,503' 0.0732 7" Liner 26/L-80/DWC 6.184 6,291' 12,183' 0.0372 TUBING DETAIL 3-1/2"._ _ Tubing I 9.3/13Cr/JFE Bear 1 2.992 1 Surface 1 11,595 0.0087 WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,458' Angle at Top Pert=15 Deg. @ 10,395' JEWELRY DETAIL No Depth Item 1 1 1,517' 1 3.5"SLB -TRMAXX SSSV W/X-Nipple-ID=2.813" Date Status GLM DETAIL: SLB - SPM -1-1/2" w/ RK Latch 2 4,095' STA 6: Patco - Dev=,VLV= LGLV, Port=16/64, ND= 3698', Date=12/3/2018 3 6,977 STA 5: Patco- Dew-, VLV= LGLV, Port= 36/64, TVD= 5566', Date=12/3/2018 4 6,291' 9-5/8"x7" Liner Top Packer 5 6,306' 9-5/8"x7"Liner Hanger 6 8,294' STA 4: Patco - Dev=, VLV= DGLV, Port= 0, TVD= 6588', Date=12/3/2018 7 9,088' STA 3: Patco - Dev=, VLV= LGLV, Port -16/64, TVD= 7349, Date=12/3/2018 8 9,888' STA 2: Patco -Der-,VLV= DMY, Port= 0, TVD=8122', Date= 9 10,191' STA 1: Patco -Dev=,VLV= OGLV, Port- 22/64, TVD=8415', Dat&=12/3/2018 30 1 10,270' 3-1/2"HES -X Nipple -ID=2.813" 11 10,311' 7"x3- 2"HES PHL Packer 12 10,363' 3-1/2- Sliding Sleeve XD -Down to Open ID=2.813")-Closed 10/25/2018 13 11,469' 7" x 3-1/2" HES PHL Packer 14 11,514' 3-1/2" HES - X Nipple - ID 2.813" 15 11,554' 3-1/2"HES -XN Nipple -ID=2.75" 16 11,594' 3-1/2"WLEG-ID=2.992"-Btm@11,595' PERFORATION DETAIL 4DSands Top (MID) Btm(MD) Top(TVD) Btrn TVD) FT Date Status Ferns 10,395' 10,405' 8,617 8,627 17 10/3/18 Shut (SSD) FIV 11,842' 11,858' 10,002' 10,017' 16'. 12/30/18 Open 2 -3/8 - FIV 11,842' 11,858' 10,002' 10,017' 16' TBD Open 2 -3/8 - FIV 11,892' 11,902' 10,050' 10,060' 10' TBD Open M2-31V FIV 11,905' 11,931' 10,062' 10,087' 26' 10/29/18 Open FIV 11,905' 11,931' 10,062' 10,087' 26' TBD Open FIV 11,950' 11,960' 10,106' 10,115' 30' TBD O en Reference Pert Log: HES MWD GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion - 10/1/1983 Revised By: WLR 6/7/2019 DATA SUBMITTAL COMPLIANCE REPORT 4/17/2019 Permit to Drill 2181060 Well Name/No. DUCK IS UNIT MPI 2-66A MD 12193 TVD 10340 Completion Date 10/7/2018 REQUIRED INFORMATION Operator HILCORP ALASKA LLC Completion Status 1 -OIL Current Status 1-0I1. API No. 50-029-22374.01-00 UIC No Mud Log No t/ Samples No � Directional Survey, Yes v DATA INFORMATION List of Logs Obtained: ROP -DGR -ADR -ABG 2"/5" MD/TVD, CASTM-CBL (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30026 Digital Data 7500 12194 11/20/2018 Electronic Data Set, Filename: MPI 2-66A AOGCC Page 1 of 4 Wednesday, April 17, 2019 DGR_ABG_ADR_ALD_CTN LWD Final.las ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final MD.cgm ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final TVD.cgm ED C 30026 Digital Data 11/20/2018 Electronic File: 2-66A - Definitive Survey Report.txt ED C 30026 Digital Data 11/20/2018 Electronic File: 2-66A Definitive Survey Report.pdf ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final MD.emf ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final TVD.emf ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final MD.pdf ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final TVD.pdf ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final MD.tif ED C 30026 Digital Data 11/20/2018 Electronic File: MPI 2-66A DGR_ABG_ADR_CTN_ALD LWD Final TVD.tif ED C 30026 Digital Data 11/20/2018 Electronic File: EMFView3_1.zip ED C 30026 Digital Data 11/20/2018 Electronic File: Readme.txt Log C 30026 Log Header Scans 0 0 2181060 DUCK IS UNIT MPI 2-66A LOG HEADERS AOGCC Page 1 of 4 Wednesday, April 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/17/2019 Permit to Drill 2181060 Well Name/No. DUCK IS UNIT MP12-66A Operator HILCORP ALASKA LLC MD 12193 TVD 10340 Completion Date 10/7/2018 Completion Status 1 -OIL ED C 30027 Digital Data 8800 12050 ED C 30027 Digital Data 12071 8761 ED C 30027 Digital Data 12052 11788 ED C 30027 Digital Data ED C 30027 Digital Data ED C 30027 Digital Data ED C 30027 Digital Data ED C 30027 Digital Data ED C 30027 Digital Data ED C 30027 Digital Data Log C 30027 Log Header Scans 0 0 ED C 30509 Digital Data 11707 12030 ED C 30509 Digital Data 10310 10530 ED C 30509 Digital Data 0 819 ED C 30509 Digital Data 0 820 ED C 30509 Digital Data ED C 30509 Digital Data ED C 30509 Digital Data API No. 50-029-22374-01-00 Current Status 1 -OIL UIC No 11/20/2018 Electronic Data Set, Filename: END_2- 66A_ACE_030CT18_ProcessedLog.las 11/20/2018 Electronic Data Set, Filename: END_2- 66A_CAST_030CT 18_Main.las 11/20/2018 Electronic Data Set, Filename: END_2- 66A_CAST_03OCT 18_Repeat.las 11/20/2018 Electronic File: END_2- 66A_ACE_030CT18_Processed Log.diis 11/20/2018 Electronic File: END_2- 66A_ACE_03OCT18_ProcessedLog.pdf 11/20/2018 Electronic File: END 2- 66A_ACE _030CT18_ProcessedLog.tif 11/20/2018 Electronic File: END_2- 66A_ACE_03OCT18_Segm entedQCLog. pdf 11/20/2018 Electronic File: END_2- 66A_ACE_03OCT18_Segm entedQCLog.tif 11/20/2018 Electronic File: END_2.66A_CAST_03OCT18.pdf 11/20/2018 Electronic File: END_2- 66A_CAST_03OCT 18_1mg.tiff 2181060 DUCK IS UNIT MPI 2-66A LOG HEADERS 3/28/2019 Electronic Data Set, Filename: END2- 66A_TMD3D 29DEC18_BottomSection.las 3/28/2019 Electronic Data Set, Filename: END2- 66A_TMD3D_29DEC 18_TopSection.las 3/28/2019 Electronic Data Set, filename: END2- 66A_TMD3D-W FL_29DEC 18_stop-11936.1as 3/28/2019 Electronic Data Set, Filename: END2- 66A_TMD3D-W FL_29DEC 18_stop-11945.1as 3/28/2019 Electronic File: END2- 66A_TMD3D_29DEC18 BottomSection.dlis 3/28/2019 Electronic File: END2- 66A_TMD3D_29DEC 18_Processed Log.pdf 3/28/2019 Electronic File: END2- 66A_TMD3D_29DEC 18_Processed Log_img.tiff AOGCC Page 2 of 4 Wednesday, April l7, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/17/2019 Permit to Drill 2181060 Well Name/No. DUCK IS UNIT MPI 2-66A Operator HILCORP ALASKA LLC MD 12193 TVD 10340 Completion Date 10/7/2018 Completion Status 1 -OIL ED C 30509 Digital Data ED C 30509 Digital Data ED C 30509 Digital Data ED C 30509 Digital Data ED C 30509 Digital Data ED C 30509 Digital Data ED C 30509 Digital Data Log C 30509 Log Header Scans Well Cores/Samples Information API No. 50-029-22374-01-00 Current Status 1 -OIL UIC No 3/28/2019 Electronic File: END2- 66A_TMD3D_29DEC 18_ TopSection.dlis 3/28/2019 Electronic File: END2-66A_TMD3D- W FL_29DEC18_ProcessedLog.pdf 3/28/2019 Electronic File: END2-66A_TMD30- W FL_29DEC18_ProcessedLog_img.tiff 3/28/2019 Electronic File: END2-66A_TMD3D- W FL_29DEC18_stop-11936.diis 3/28/2019 Electronic File: END2-66A_TMD3D- W FL_29DEC18_stop-11945.dils 3/28/2019 Electronic File: END2- 66A_TMD3D_29DEC18.pdf 3/28/2019 Electronic File: END2- 66A_TMD3D_29DEC18_img.tiff 2181060 DUCK IS UNIT MPI 2-66A LOG HEADERS Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report O Directional / Inclination Data O Mud Logs, Image Files, Digital Data Y / I A� Core Chips Y Production Test Information@ NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files J Y('J �/'�) Core Photographs Y / IA Geologic Markers/Tops O Daily Operations Summary 0 Cuttings Samples �Y/Rvn Laboratory Analyses Y /�J�A COMPLIANCE HISTORY Completion Date: 10/7/2018 Release Date: 9/6/2018 Description Date Comments AOGCC Page 3 of 4 Wednesday, April 17, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/17/2019 Permit to Drill 2181060 Well Name/No. DUCK IS UNIT MPI 2-66A Operator HILCORP ALASKA LLC MD 12193 TVD 10340 Completion Date 10/7/2018 Completion Status 1-0I1 Current Status 1-011- Comments: -OIL Comments: Compliance Reviewed By: Date: API No. 50-029-22374-01-00 UIC No AOGCC Page 4 of Wednesday, April 17, 2019 21 91 06 Debra _ .dean Hilcorp Alaska, LLC 30 50 9 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 nilenq LIA Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 3/27/2019 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 RECEIVED MAR 2 8 2019 AOGCC CBL data ANALYSIS GASSAT []END2-66ATMD3D_29DECl8BMcrnSect... 1/3/20194:50PM DLIS File 157 KB END2-66ATMD3E129DEC18BottomSe _ 1/3120194:50 PM LAS File 277 KB / EN02-66A-TMD31) 29DEC18 Proc.s edl_ 1/3/20194:44 PM PDFDecument 5,164 KB D END2-66A_TMD3D 29DEC18 Prcce SedL... 1/3120194:43 PM TIFF File 9, 388 KB END2-66A-TMD3D29DEC18TopSection.... 1/320194A7 PM DLIS He 112 KB ,END2-66A_TMD3D29DEC18TopSedion 1/3/20194:47 PM LAS File 189 KB WFLT END2-66ATMD3D-WFL29DEC18Prom.. 1213012018 5,33 AM PDF Document 7,522 K6 W END2-66A_TMD3D-WFL_29DEC18 Proce... 12/30/20185:32 AM TIFF File 14,244 KB ❑END2-66ATMD3D-WFL29DEC18_Aop-1... 2/11/20193:27 PM DLIS File 1,714 KB END2-65ATMD3D-WFL29DEClEAop-1... 2/11/20193.27 PM LAS File 104 KB [j END2-66ATMD3D-WFl29DEC18rtop-1... 2111/20193:26 PM DLIS File 1,7160 -1 END2-66A_TMD3D-WFL 29DEC18 stop -1... 2,'11/20193:26 PM LAS File 102 KB FIELD DATA o END2-66A_TMD3D_29DEC18 2/11,/2019 3:11 PM PDF Document 3,411 KB W END2-66A_TMD3D_29DEC78_img 2'1120193:11 PM TIFF File 9,131 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 STATE OF ALASKA I ALA_.,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '=CEIVE® JAN 0 7 2019 1. Operations Abandon Plug Perforations Performed: Suspend ❑ Perforate ❑ Fracture Stimulate Pull Tubing ,gpgrati Li Other Stimulate❑ Alter Casing ❑ Char9de�n9PPlro m ❑ Plug for Redrill ❑ Perforate New Po❑✓ Repair Well❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Fl ✓ 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑� Stratigraphic ❑ Exploratory ❑ Service ❑ 218-106 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 6. API Number: 99503 50-029-22374-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL034633 DIU MPI 2-66A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Endicott Field / Endicott Oil & Seabee Undefined Pool 11. Present Well Condition Summary: Total Depth measured 12,193 feet Plugs measured 12,057 feel true vertical 10,340 feet Junk measured 11,554 feet 6,291, 10,311 & Effective Depth measured 12,193 feet Packer measured 11,469 feet 5,113, 8,530 & true vertical 10,340 feet true vertical 9,644 feel Casing Length Size MD TVD Burst Collapse Conductor 134' 20" 161' 161' N/A N/A Surface 2,845' 13-3/8" 2,872' 2,739' 5,020psi 2,260psi Production 7,503' 9-5/8" 7,503' 5,933' 6,870psi 4,760psi Liner 5,892' 7" 12,183' 10,330' 10,160psi 10,540psi Perforation depth Measured depth See Schematic feel True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / 13Cr / JFE Bear 11,595' 9,765' 9-5/8" x 7" LTP 1,517 MD Packers and SSSV (type, measured and true vertical depth) (2) 7" X 3.5" PHL See Above TRMAXX SSSV 1,513 TVD 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 1,000 265 Subsequent to operation: 160 1,830 523 11,550 1 283 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-465 Authorized Name: Bo York Contact Name: Taylor Wellman Authorized Title: Operations Manager Contact Email: twellman(d7.hllcoM.com Authorized Signature: Date. 1/4/2019 Contact Phone: 777-8449 V Form 10-404 Revised 4/2017 1R13DMSQ3N�JAN 0 9 2019 Submit Original Only n Nil,.m Alaska. IAA: KB Bcv.: 401 BF/Gl- Ek -v-: 13.3' To=12,193' (MD) / TD=10,34(Y(IVD) Pan) =12,057 (ND) / P9fD=10,21)B'(TVD) SCHEMATIC Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD H25 Readings Average 230 -260 PPM on A/l &Gas Injectors Tree 4-1/16" CIW Well hasa SSSV I Wellhead I CAM OPEN HOLE / CEMENT DETAIL 13-3/8" 4,557 cu/ft Permafrost in 17.5" Hole 9-5/8" li 575 cu/ft Class'G' in a 12-1/4" Hole 7„ Stg 1126 sx of 14.5 ppg Class G-308BLS Stg 2 111 sx of 15.8 ppg Class G -23 BBLS CASING DETAIL Size Type Wt/ Grade/ Cann Drift ID Top BtmJBP20" Date Status Conductor N/A/N/A/N/A N/A Surface 161'13-3/8" 6,970' STA S: Patco - Dev=. VLV= LGLV, Port= 16/64, TVD= 5566', Date=12/3/2018 Surface 68/ N-80/ Btrs 12.415 Surface 2,872'9-5/8" 9-5/8"0" Liner Hanger 6 Production 47/NT805/NSCC 8.681 Surface 7,503'7" 8 9,888' Liner 26/L-80/DWC 6.184 6,291' 12,183' 10,270' TUBING DETAIL 3-1/2" Tubing 9.3/13Cr/1FE Bear 1 2.992 1 Surface 1 11,595 0.0087 WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,458' Angle at Top Perf=15 Deg. @ 10,395' JEWELRY DETAIL No Depth Item 1 1,517' 3.5"5113-TRMAXX SSSV w/X-Nipple-ID=2.813" Date Status GLM DETAIL: SLB - SPM -1-1/2" w/ RK Latch 2 4,095' STA 6: Patco - Dev=, VLV= LGLV, Port=16/64, TVD= 3698', Date=12/3/2018 3 6,970' STA S: Patco - Dev=. VLV= LGLV, Port= 16/64, TVD= 5566', Date=12/3/2018 4 6,291' 9-5/8"0" Liner Top Packer 5 6,306' 9-5/8"0" Liner Hanger 6 8,294' STA 4: Patco- Dev=, VLV= DGLV, Port= 0, TVD= 6588', Date=;12/3/2018 7 9,088' STA 3: Patco- Dev=, VLV= LGLV, Port= 16/64, ND., 7349', Date=12/3/2018 8 9,888' STA 2: Patco- Dev=, VLV= DMY, Port= 0, ND= 8122', Date= 9 10,191' STA 1: Patco - Dev=, VLV= OGLV, Port= 22/64, TVD= 8415', Date=12/3/2018 10 10,270' 3-1/2"HES -X Nipple -ID=2.813" 11 1 10,311' 1 7"x3-1/2"HES PHL Packer 12 10,363' 3-1/2" Sliding Sleeve (ID=2.813")-Closed 10/25/2018 13 11,469' 7"x3-1/2"HES PHL Packer 14 11,514' 3-1/2"HES -% Nipple -ID 2.813" 15 11,554' 3-1/2"HES -XN Nipple - ID= 2.75" 16 11,594' 3-1/2' WLEG - ID= 2.992" - Btm @ 11,595' PERFORATION DETAIL ENDSands Tap (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Ferris 10,395' 10,405' 8,610' 8,620' 10' 10/3/18 Shut(SSD) fN 11,842' 11,858' 10,002' 10,017' 16' 12/30/18 Open FN VI 11,905' 1 11,931' 10,062' 10,087' 26' 10/29/18 Open Reference Perf Log: HES LWD GE NERAL WELL INFO API: 50-029-22374-01-00 Initial Completion - 10/1/1983 Revised By: TDF 1/4/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A Slickline 50-029-22374-01-00 218-106 10/25/2018 12/30/2018 Daily Operations. 10/24/2018 - Wednesday No activity to report. 10/25/2018 -Thursday PT PCE TO 250psi LOW - 3,000psi HIGH F. B&F TBG TO X -LOCK & FLOW THROUGH SUB. PULL X -LOCK W/ FLOW THROUGH SUB & GAUGES FROM 10,266' SLM. SHIFT XD SLIDING SLV UP TO CLOSE @ 10,351' SLM. DRIFT FREELY TO TO @ 12,047' SLM W/ 29'x 2.29" DUMMY PERF GUNS, W/ 2.40" CENT ON TOP & 2.68" CENT ON BTM. 10/26/2018 - Friday No activity to report. 10/27/2018 -Saturday PT PCE TO 250psi LOW - 3,000psi HIGH. DRIFT & TAG TO @ 12,051' SLM W/ 2.70" SWEDGE (see fluid level @ 10,200' slm 10,212' and ). 10/28/2018 -Sunday No activity to report. 10/29/2018 - Monday PT PCE 325 LOW 4,000' HP. PERFORATE 11,905' - 11,931' RKB W/ 6 SPF, 60 DEG PHASED GUN, 11 gm, CONNEX CHARGES. 10/30/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A Slickline 50-029-22374-01-00 218-106 10/25/2018 12/30/2018 Daily Operations. 11/14/2018- Wednesday No activity to report. 11/15/2018 - Thursday No activity to report. 11/16/2018 - Friday No activity to report. 11/17/2018 -Saturday No activity to report. 11/18/2018 -Sunday No activity to report. 11/19/2018 - Monday ***WELL SHUT IN UPON ARRVAL, NOTIFY PAD -OP, PT PCE 250L/2,000H*****. SET 3-1/2" KEYLESS X -LOCK CATCHER (21") IN XN- NIPPLE @ 11,514' SLIM / 11,554' MD. LAID EQUIP DOWN FOR THE NIGHT- LEAVE IN WELL OVERNIGHT. 11/20/2018 -Tuesday ***WELL SHUT IN UPON ARRVAL, NOTIFY PAD -OP, PT PCE 250L/2,000H*****. PULL STA# 1, 3, 4, 5, & 6. SET NEW GASLIFT DESIGN IN SAME. LAY DOWN FOR NIGHT- LEAVE WELL SHUT IN. WILL RETURN TO PULL CATCHER AND RUN PRESS/TEMP LOG. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A Slickline 50-029-22374-01-00 218-106 10/25/2018 12/30/2018 Daily Operations. 11/21/2018- Wednesday CREW C/O* PT PCE 250L/3,000H*****. PULL 3-1/2" KEYLESS X -CATCHER FROM 11,514'(11,554- MD) . RUN PDS MPL TOOL AS PER PROGRAM (good data). 11/22/2018 - Thursday No activity to report. 11/23/2018 - Friday No activity to report. 11/24/2018 -Saturday No activity to report. 11/25/2018 -Sunday No activity to report. 11/26/2018 - Monday No activity to report. 11/27/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A Slickline 50-029-22374-01-00 218-106 10/25/2018 12/30/2018 Daily Operations, 11/28/2018- Wednesday No activity to report. 11/29/2018 - Thursday No activity to report. 11/30/2018 - Friday No activity to report. 12/1/2018 -Saturday No activity to report. 12/2/2018 -Sunday PT PCE 250psi LOW - 3,000psi HIGH. PULLED STA.#1 RK-DGLV FROM 10,162' SUM (10,191' MD). PULLED STA.#3 RK-DGLV FROM 9,062' SLM (9,088' MD). PULLED STA.#4 RK-DGLV FROM 8,270' SUM (8,294' MD). PULLED STA.#6 RK-LGLV FROM 4,070' SLM (4,095' MD). PULLED & CUT 4,450' OF .125 STAINLESS DUE TO BEING PINCH ON SIDE OF DRUM & UNDER ON STRAND OF WIRE. 12/3/2018 - Monday PT PCE TO 250psi LOW - 3,000psi HIGH (pass). PULLED STA.#5 RK-LGLV FROM 6,949'SUM (6,970' MD). SET RK-LGLV IN STA.#6 @ 4,070' SUM / 4,095' MD (16/64" port, 1800psi TRO). SET RK-LGLV IN STA.#5 @ 6,949'SUM / 6,970' MD (16/64" port, 1802psi TRO). SET RK-DGLV IN STA.#4 @ 8,270' SLM (8,294' MD). SET RK-LGLV IN STA.#3 @ 9,062' SLM / 9,088' MD (16/64" port, 1802psi TRO). SET RK-DGLV IN STA.#1 @ 10,162' SLM / 10,191' MD (22/64" orifice). PULL EMPTY 3-1/2" KEYLESS X -CATCHER FROM XN-NIP @ 11,520' SLM (11,554' MD). ***WELL FLOWING ON DEPARTURE, WELL TENDER NOTIFIED*** 12/4/2018 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-66A Slickline 50-029-22374-01-00 218-106 10/25/2018 12/30/2018 Daily Operations, 12/26/2018 - Wednesday No activity to report. 12/27/2018 - Thursday No activity to report. 12/28/2018 - Friday No activity to report. 12/29/2018 -Saturday WELL S/I ON ARRIVAL(wf log, perf). PT PCE 2501-13-2,000HP(good). RAN HES WF LOG IN SIGMA MODE. LOGGED UP PASS FROM 12,035' TO 11,700' IN THE 7" CSG. LOGGED UP PASS FROM 10,500' TO 10,300' IN 3-1/2" TBG. LOG STATION STOPS @ 11,945' & 11,936'. LAY DOWN FOR THE NIGHT - NOTIFIED PAD OP. 12/30/2018 -Sunday PT PCE 250LP-2000HP(good). PERFORATE FROM 11,842'- 11 858'RKB W/ 2-3/8", 6 SPF, 60 DEG, 11.0 gr. GEO CONNEX CHARGES. (tied into LWD dated 27 -Sept -2018). WELL LEFT S/I ON DEPARTURE - TURNED OVER TO OPS. 12/31/2018- Monday No activity to report. 11/1/2018 -Tuesday No activity to report. Ar Debra Oudean 80rAlaska, LLC 30C GeoTech 3800 enterpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Nilangi %6A.-LLL Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 11/19/2018 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 RECEIVED NOV 2 0 2018 AOGCC HALLIBURTON FINAL DATA CGM MPI 2-66A DGR ABG ADR_CTN ALD LWD Final Mocgm 9/30/20181:38 PM CGM File MPI 2-66A DGR ABG ADR_CrN ALD LWD Final TVD.cgm 9/30/20181:40 PM CGM File EMF ,d MP12-66A DGRABG_ADR CTN ALD LWD Final MDemf 9/30/201812:45 PM EMF File `d MP12-66A DGRABGADRCENALD LWD Final TVD.emf 9/30/201812:56 PM EMF File LAS ® MPI 2-66A DGR ABG ADR_ALD GTN LWD Final.las 9/30/20181:28 PM LAS File PDF 12 MPI 2-66A DGR ABG_ADR_CENALD LWD Final MD.pdf 9/30/20181:39 PM PDF Document G MPI 2-66A DGRABG_ADR CrN ALD LWD Final TVD.pdf 9/30/20181:40 PM PDF Document TIFF • MPI 2-66A DGR_Al3G_ADR_CFN_ALD LW... 9/30/20181:38 PM TIFF image • MP12-66A DGR ABG_ADR CTN_ALD LW... 9/30/20181:40 PM TIFF image DEFINITIVE SURVEY 2-66A - Definitive Survey Report.txt 10/3/201810:06 A... Text Document p 2-66A Definitive Survey Report.pdf 10/3/2018 10:06 A... PDF Document 218106 30026 Please include current contact information if different from above. Please acknowledge rglceipt by siggng and rete ning o copy of this transmittal or FAX to 907 777.8337 Received By: r r Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 liil.i,p Al:.ka. LLC Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 11/19/2018 21 8106 30027 To: Alaska Oil & Gas Conservation Commission �,`'�.® Natural Resource Technician AC`' �/ 333 W 7th Ave Suite 100 �{G 2 2�1a Anchorage, AK 99501 �ov P0GG MPI 2-66A (218-106 CBL data ANALYSIS END_2-66A, ACE 030CT18 Processedlog.dlis 11/6/2018 2:30 PM DLIS File 50632 KB `ENDS-66kACE_030Cr18yrocessedLog.las 11/6/20182:30 PM LAS File 5.631 KB v ENDS-66AACE_030CT18 ProcessedLog.pdf 11/6/2018 2:13 PM PDF Do amen 27,418 KB END2-66AACE 0317CT18yrmc sedLog.tif 11/6/2018 2:13 PM TIFF image 16,057 KB 0 END2-66AACE 03DCT18-SegMMedQCLog.Pdf 11/6/2018 2:13 PM PDF Document 17,457 KB =a END 2-66A.ACE 030CT18_SegmentedQCLog.tif 11/6/2018 2:13 PM TIFF image 9,407 KS FIELD DATA IP' END 2-66A_CAST 030CT1&pdf 11/6/2018 2:43 PM PDF Document 7,456 KB I;. END_2-66A_CAS1_030CT18 imgAff 11/6/20182:34 PM TIFF File 22,344 KB ', END_2-66A-CAST 030CT18 Maimlas 11/6/2018 2:52 PM LAS File 3,896 KS Li END 2-66A_CAST_030CT18-RepeatlaS 11/6/2018 2:52 PM LAS File 315 KB Please include current contact information if different from above. Please acknowledge>feceipt by signinccland retyrning one copy of this transmittal or FAX to 907 777.8337 Received By:/ P // //A �/ / I I Date: b1fp Z HMinilvL.1111.0 STATE OF ALASKA NOV 0 5 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN C 1a. Well Status: oil 21 Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended E] 20AAC 25.105 20MC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: _ 1 1b. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend.: 10/7/2018 14. Permit to Drill Number / Sundry: • 218-106 / 318-430 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: September 19, 2018 15. API Number: 50-029-22374-01-00' 4a. Location of Well (Governmental Section): Surface: • 3152' FSL, 2360' FEL, Sec 36, T12N, R16E, UM, AK . Top of Productive Interval: 936' FSL, 940' FEL, Sec 35, T12N, R16E, UM, AK Total Depth: 1368' FSL, 1193' FEL, Sec 35, T12N, R16E, UM, AK 8. Date TO Reached: September 26, 2018 16. Well Name and Number: DIU MPI 2-66A ' 9. Ref Elevations: KB: 40' • . GL:13.3' F:13.3' 17. Field / Pool(s): Endicott Field - Seabee Undef / Endicott Oil Pool. 10. Plug Back Depth MD/TVD: • 12,057' MD / 10,208' TVD - 18. Property Designation: ADLO34633 - 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 258840 ' y- 5982293 ' Zone- 3 TPI: x- 254912 y- 5980203 Zone- 3 Total Depth: x- 254673 y- 5980644 Zone- 3 11. Total Depth MD/TVD: • 12,193' MD / 10,340' TVD. 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: 1,517' MD / 1,513' TVD 20. Thickness of Permafrost MD/TVD: - 1,465' MD / 1,462' TVD 5. Directional or Inclination Survey: Yes J (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: . 7,503' MD / 5,933' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP -DGR -ADR -ABG 2"/5" MD/TVD CASTM-CBL 10-3-18 C 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT HOLE SIZE CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 7" 26# L-80 6,291' 12,183' 5,113' 10,330' Stg1-L-126 sx 8-1/2" Stg 2 - L - 111 sx 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 10,395' - 10,405' MD / 8,610' - 8,620' TVD; 3-3/8"; 6 SPF; 10/3/18 r Above perf is open but is stradled by packers and the sliding sleeve is closed, of producing into wellbore. 1,905' - 11,931' MD / 10,062' - 10,087' TVD; 2-3/8", 6 SPFi; (DWEVTION � DATE o P);li /o /� /' —/0 / re VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDITVD) 3-1/2" 11,595' 10,311' / 8,530' 11,469' / 9,644' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No J Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. t'rc�,i PRODUCTION TEST Date First Production: 10/31/2018 Method of Operation (Flowing, gas lift, etc.): Gas Lift Date of Test: 10/31/2018 Hours Tested: 24 Production for Test Period Oil -Bbl: 103.6 Gas -MCF: 2028 Water -Bbl: 797 Choke Size: N/A Gas -Oil Ratio: 19575 Flow Tubing Press. 260 Casing Press: 1650 Calculated 24 -Hour Rate _-J� Oil -Bbl: 103.6 Gas -MCF: 2028 Water -Bbl: 797 Oil Gravity - API (corr): 23.5 Form 10-407 Revised 5/2017 $O 3 �O CONTINUED �ONF/5 2 RED' 'S � ^ f / K`?il 0 5 2018 Submit ORIIGGIINIAL onygl 28. CORE DATA Conventional Core(s): Yes ❑ No Sidewall Cores: Yes ❑ No Q - If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 1,465' 1,462' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval FIV 11,905' 10,062' information, including reports, per 20 AAC 25.071. Top Fenris 10,393' 8,609' Base Fenris 10,406' 8,621' Top Tuff 10,459' 8,672' Top HRZ 10,982' 9,176' LCU 11,251' 9,434' Top FV 11,842' 10,002' Top FIV 11,891' 10,049' Top FIII 12,001' 10,155' Top FII 12,074' 10,225' Formation at total depth: FII (Kekiktuk) 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report 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. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: edip-ger@hiloorp.com Authorized Contact Phone: 777-8389 _ Signature: -- Date: ( I ' `7 Z O j 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, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. 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 5/2017 Submit ORIGINAL Only K caro Alaska, LLC KB Elev.: 40'/ BF/GL Elev.: 13.3' Mn 10=275" @ 11,554' TD =12,193' (MD) / TD=10,340'(1VD) PBTD =12,057' (NO) / PBM =10,2WOVD) SCHEMATIC Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD H25 Readin s Avera a 230-260 PPM on A/L & Gas In'ectors Tree 4-1/16' CWLd Well has a SSSV WeYhead CtVN OPEN HOLE / CEMENT DETAIL 13-3/8" 4 557 cu/ft Permafrost in 17.5" Hole 9-5/8" 575 cu/ft Class'G' in a 12-1/4' Hole P 7" Stg 1 126 sx of 14.5 ppb Class G - 30 RBIs X StS 2111 sx of 15.8 ppg Class G-238815 V' GS CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor N/A / N/A N/A N/A Surface 161' N/A 13-3/8' Surface 68/ N-80/ Bus 12.415 Surface 2,872' 0.150 9-5/8" Production 47/NTBOS/NSCC 8.681 Surface 7,503' 0.0732 7" Liner 26/L-80/DWC 6.184 6293' 12,183' 0.0372 TUBING DETAIL WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,456' Angle at Top Perf= 15 Deg. @ 10,395' JEWELRY DETAIL No Depth Item 1 1,517' 3.5" SLB - TRMAXX SSSV w/ X -Ni le - ID= 2.813' 8,610 8,620 10 10/3/18 3-3/8' GLM DETAIL: SLB - SPM -1-1/2" W/ RK Latch 2 4,095' STA 6: Patco - Dev=, VLV= DMY, Port= 0, TVD- 3698, Date=10/19/2038 3 6,970' STA 5: Patco - Der- VLV= DMY Port= 0, TVD= 5566, Date=10/19/2018 4 6,291' 9-5/9"0' Liner TopPacker 5 6,3W 9-5/8"0" Liner Hariller 6 8,294' STA 4: Patco - Der-, VLV= Dome, Port= 16/64, ND= 6588', Dat"10/20/2018 7 9,088' STA 3: Patco - Dew, VLV= Dome, Port=16/64, TVD- 7349', Date=10/21/2018 8 9,888' STA 2: Patco - Der-, VLV= DMY, Port= 0, TVD- 8122', Date= 9 10,191' STA 1: Patco - Der=, VLV= S/O, Port= 24/64, TVD= 8415', Date=10/21/2018 10 10,270' 3-1/2'HES -X PI Ie -to -2.813' 11 10,311' 7' x 3-1/2' HES PHL Packer 12 10,363' 3-1/2' Sliding Sleeve ID=2.813" 1331,461 7" x 3-1/2' HES PHL Packer 14 11,514' 3-1/2"NES-XNi le -ID 2.813" 15 11,554' 3-1/2' HES - XN Nipple - ID- 2.75" 16 11,594' 3-1/2" W LEG - ID= 2.992" - Stm @ 11,595' PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Size s Fenris 10,395' 10,405' 8,610 8,620 10 10/3/18 3-3/8' FIV 11,905' 11,931' 10,062' 10,08T 26' 10/28/182 -3/8 - t0ppen Reference Perf Log: HES LWD GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion letion - 10/1/1983 Revised By: CID 11/05/2018 i 5r Hilcorp Energy Company CASING & CEMENTING REPORT Lease 8 Well No. END 2-66A Casing (Or Liner) Detail Date Run 29 -Sep -18 County State Alaska Supv. As. Component CASING RECORD Wt. Grade THD Liner Length Bottom TD 12,193.00 Shoe Depth: 12.183.00 PBTD: 12.057.00 Liner hanger test pressure: No. Jts. Delivered 150 No. As. Run 148 No. Jts. Returned 2 Length Mmsurwnentx WT Threstls FM IlMi-r! 5 HAS Al Fln Rim 5 Al. 59 Fln Rarumed 7R 01 Gag Wt. On Hook: 280 Type Float Collar: Conventional Casing (Or Liner) Detail 25.5 Csg Wt. On Slips: Type of Shoe: Bullnose Setting Depths As. Component Size Wt. Grade THD Make Length Bottom Top Baker Flex Lock Float Shoe 85/8 Liner hanger test pressure: BTC X Yes No 2.65 12,183.00 12,180.35 2 Casing 7 26.0 L-80 DWC/C 1 ea: Joint 39 - 44: three joints above and below ES Cementer 79.74 12,180.35 12,100.61 1 e/ other joint from Y48 through #60 Float Collar 85/8 CEMENTING REPORT BTC Type: Drilling fluid 1.33 12,100.61 12,099.28 1 Casing 7 26.0 L-80 DWC/C Casing Rotated? 41.31 12,099.28 12,057.97 90.5 Baffle Adapter 85/8 _Yes X No Spacer retums?_Yes BTC Halliburton 1.03 12,057.97 12,056.94 38 Casing 7 26.0 L-80 DWC/C Bond Log 1,494.56 12,056.94 10,562.38 Stage Collar@ 10541.48 Casing Pup Joint 7 26.0 L-80 DWC/C 18.18 10,562.38 10,544.20 ES Cementer 85/8 Density (ppg) 10.5 Volume pumped (BBLs) DWC/C Halliburton 2.72 10,544.20 10,541.48 Casing Pup Joint 7 26.0 L-80 DWC/C Sacks: 117 Yield: 19.00 10,541.48 10,522.48 107 Casing7 23 Miring / Pumping Rate (bpm): 26.0 L-80 DWC/C 10,522.48 6,319.57 v Casing Pup Joint 7 26.0 L-80 DWC/C 0 .01 6,319.57 6,314.56 5 Volume (actual / calculated): ck Liner Han er 7 26.0 L-80 DWC/C Baker.58 g4,202.91 6,314.56 6,305.98 X No Reciprocated? HRDEZXHD LinerTopPacker 7 26.0L-80 Cement returns to surface? DWC/C Baker.13 X No Vol to Surf. 6,305.98 6,290.85 Gag Wt. On Hook: 280 Type Float Collar: Conventional No. Hrs to Run: 25.5 Csg Wt. On Slips: Type of Shoe: Bullnose Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg _ Yes X No 15 Ft. Min. 10.3 PPG Fluid Description: 6% KCL GEM GP Density (ppg) Liner hanger Info (Make/Model): Baker Flex Lock Liner top Packer?: X Yes -No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 2 as: joint 1, 3 _ Sacks: 126 Yield: 1 as: Joint 2 and joint 4 through 25 (11194.44') Density (ppg) 14.5 1 ea: Joint 39 - 44: three joints above and below ES Cementer 30 Mixing / Pumping Rale (bpm): 2.6 yDisplacement: 1 e/ other joint from Y48 through #60 CEMENTING REPORT Type: Drilling fluid Post Job Calculations: Calculated Cmt Vol @ 0% excess: 38.5 Total Volume cmt Pumped: 53 Cmt returned to surface: 0 Calculated cement left in wellbore: 53 OH volume Calculated OH volume actual: Actual % Washout: www.vvellez.net WellEz Information Management LLC ver 04818br Shoe @ 12183 FC @ 12,056.94 Top of Liner 6290.85 Preflush (Spacer) Type: Clean Spacer Density (ppg) 10.5 Volume pumped (BBLs) 33 Lead Slurry Type: Class G Sacks: 126 Yield: 1.33 Density (ppg) 14.5 Volume pumped (BBLs) 30 Mixing / Pumping Rale (bpm): 2.6 yDisplacement: Type: Drilling fluid Density (ppg) 10.3 Rate (bpm): 4 Volume (actual I calculated): 324.5/326.5 E FCP (psi): 662 Pump used for lisp: Rig pump Bump Plug? X Yes _No Bump press 1150 Casing Rotated? Yes X No Reciprocated? _Yes X No % Returns during job 90.5 Cement returns to surface? _Yes X No Spacer retums?_Yes X No Vol to Suff. 0 Cement In Place At: 22:06 Date: 10/1/2016 Estimated TOC: 11530' / Method Used To Determine TOC: Bond Log Stage Collar@ 10541.48 Type ES Cementer Closure OK Yes Preflush (Spacer) Type: Clean Spacer Density (ppg) 10.5 Volume pumped (BBLs) 33 Lead Slurry w Type: Class G Sacks: 117 Yield: 1.16 F Density (ppg) 15.8 Volume pumped (BBLs) 23 Miring / Pumping Rate (bpm): 2 m Displacement: v 0 Type: Dolling fluid Density (ppg) 10.3 Rate (bpm): 5 Volume (actual / calculated): 267.5/269 w FCP (psi): Boo Pump used for disp: Rig Bump Plug? X Yes No Bump press 2500 Casing Rotated? _Yes X No Reciprocated? Yes X No % Returns during job 100 Cement returns to surface? _Yes X No Spacer retums?_Yes X No Vol to Surf. 0 Cement In Place At: 6:30 Date: 10/2/2018 Estimated TOC: 9230' Method Used To Determine TOC: CBL Post Job Calculations: Calculated Cmt Vol @ 0% excess: 38.5 Total Volume cmt Pumped: 53 Cmt returned to surface: 0 Calculated cement left in wellbore: 53 OH volume Calculated OH volume actual: Actual % Washout: www.vvellez.net WellEz Information Management LLC ver 04818br ffHilcorp Energy Company Composite Report Well Name: END 2-66A Field: Endicott County/State: ,Alaska i (LAT/LONG): ovation (RKB): API #: Spud Date: 9/20/2018 Job Name: 1811485D END 2-66A Drilling Contractor Innovation APE If APE $: Activity Date _ Ops Summary 9,15/2018 PJSM Prep and scope down Derrick. Remove Derrick cables. R/D Mezz mud lines, cutting box, blow down water and steam. Prep all rig roofa;PJSM Walk Sub out from well 1-29. Hook up hydaulic fittings for rear tires and install. Install yoke and move to new well END 2-26A. Remove yoke and rear tires. Walk Sub onto well. Put MP #1 valves, swabs and liners back together. Spot Catwalk, Pipe Shed and Mud Mob. Begin to spot Motor Mod.;Work on inner connects as each Mod was spotted. Put MP #2 valves, swabs and liners back together. Replaced 1 wash plate. R/U 1502 hose off well for bleed Iine.;Daily Fluid Hauled to MP G&I: 0 bbis Total Fluid Hauled to MP G&I:0 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT: 0 bbls Daily Fluid Hauled to Milne B-50: 0 bbis Total Fluid Hauled to Milne B50: 0 bbls;Daily H2O from Duck Lake: 0 bbis Total H2O from Duck Lake: 0 bbls Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation: 0 bbls 9/16/2018 RU pit interconnect, Hook up svc lines between modules. Hook up lines in pits and test equipment (no issues). Dress shakers w/ 140's. Load pits with 290 bbis mud. Spot shacks and hook up same. Build containment and set cuttings box. C/O manual crown saver. Troubleshoot drawworks Ethernet coms;R/U and tbg and bled back 1/4 to 1/2 bbl diesel from well to flowback tank. Shut in and allow to build back to 145 psi over 30 min. Bleed off and continue to monitor flowback @ 5 gal 14 min 33 initial then stabilized @ 5 gal / 10 min 20 we +/-. Set TWC and N/D tree. Ni Scope derrick.;Rig accepted at 16:00.;N/U BOPE;PJSM R/U Test Equip. and 5" test joint.;PJSM Test BORE W/ 5" test joint. Test Pree. 250 PSI low and 4,000 PSI high. Tested Annular, Choke valves 1-15,2 7/8"X 5 1/2" Variable Upper and Lower Pipe Rams, TIW, Dart, Kill and Choke HCR, manual HCR and Choke, Super and Manual Choke, Blind Rams. Upper and lower IBOP.;Perform Kearney draw down, initial starting Press. Manifold 1,350 PSI, Accumulator 3,000 PSI, Annular 1,375 PSI, after function Manifold 1,500 PSI, 1,550 PSI, Annular 1,500 PSI, 200 PSI increase in 25 Sec, full charge 95 Sec. 6 bottles Nitrogen average 2,291 PSI.;Test witnessed by AOGCC Austin McCloud ;R/D test Equip. and break down 5" test joint.;Daily Fluid Hauled to MP G&I:0 bbls Total Fluid Hauled to MP G&I: 0 bbis Daily Fluid Hauled to ORT: 0l is Total Fluid Hauled to ORT: 0 bbis Daily Fluid Hauled to Milne B-50:0 bbis Total Fluid Hauled to Milne B-50: 0 bbls;Daily H2O from Duck Lake: 0 bbis Total H2O from Duck Lake: 0 bbis Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation: 0 bbis 9/17/2018 RID and UD BOP test equipment. B/D all lines and svc choke, line up choke for milling operations. Clean and clear rig floor.;Service rig - Grease TDS, Blocks, Crown and prep pipeshed for picking up 5" DP.;Troubleshoot PLC communication fault issue. Clean and svc connections, Inspect for routing and install jumpers to bypass potential com line issues. PLC faulted 1x after changes then was reset without further issue. Continue with well opemtions.;PJSM M/U X/O to 5" D.P. Set in Hanger and pull Hanger W/ 20K over to unseat. P/U weight 55K. Check well for flow. (Static) Pull to floor and LID Hanger and 3' Pup. Shut in IA and Prep pits for returns. P/U Wear Ring 8 3/4" ID and set. RILDS 4ea.;M/U BOT 9.625" Test Packer 51A4 (13.6' length). Single in hole on 5" dp F/ surface to 6,485' MD. Drift pipe 2.82'. Broke circulation @ 500'to displace out remaining 35 bbis diesel in wellbore before continuing to trip in hole.;PJSM Cont to single in hole W/ 5" D.P. F/ 6,485' to 7,365' MD. P/U 175K, SLK 125K. Calculated displacement.;CBU at 7,365' MD. 168 GPM, 15-130 PSI, FO 31.7%. Max Gas 980U. Gas breaking out at surface with no gain in pit. Decision was made to displace well to 9.6 ppg 3% KCL LSND.;PJSM for displacing well W/ all personnel. Shut down monitor well. Gas cont. to break out at surface. Fluid dropping to lower rams. SIMOPS build Hi Vis Spacer.;Displace well from Seawater to 9.6 ppg 6% KCL LSND. Pump 31 bible 9.6, 208 sec Hi Vis spacer and chase with 500 bbis 9.6 ppg 6% KCL LSND at 168 GPM ICP 23 PSI FCP 225 PSI. Max Gas 1,052U. Mud weight in and out 9.55 ppg. Shut down monitor well for 10 Min. Static.;PJSM for setting Packer and testing casing. Set Test Packer at 7,363' MD W/ 2 turns to right working string as per Baker Rep onsite. P/U 167K, SLK 127K. Set down 16K. Good set. Attempt 9 5/8" casing test pumping at .75 bpm, pumped 10 bbis, casing pressure at 1,620 PSI (no test).;Shut in and monitor Csg Press., bleeding down. Bled back 3.9 bbls. LID 5" D.P. single for even stands. Set Test Packer at 7,333' MD W/ 20k set down as per BOT. Attempted testing 9 518" Csg at 1 bpm, pumped 6.6 bbis to 1,619 PSI (no test).;Shut in and monitor Csg Press., bleeding down . Bled back 4.7 bbis. Still having multiple PLC faults during operations.;Monitor well. Blow down Top Drive. POOH racking back 5" D.P. F/ 7,333'to 6,827" MD. PN 167K. Set Packer W/ 25K as per BOT. Continue having PLC faults during operations.;Close Upper Variable Rams and line up to test. Attempt to test 9 5/8" Csg at 6,82T MD at 1 bpm, pumped 4.4 bbis to 2,532 PSI. Press. bled down to 1,622 PSI. Bumped up Press F/ 1,622 PSI to 2,600 PSI at i bpm, pumped 4.4 bbis. Total pumped 8.8 bbls.;Bled back down to 1,637 PSI. Bleed back 2.9 bbis. Line up surface Equip. for POOH. Continue having PLC faults during operafions.;SPR at 7,328' MD (5,804' TVD) W/ 9.55 ppg MW MP #1 32-205 PSI, 48-227 PSI MP #2 32-200 PSI, 48-222 PSI;Daily Fluid Hauled to MP G&I: 0 bbis Total Fluid Hauled to MP G&I: 0 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT: 0 bible Daily Fluid Hauled to Milne B-50: 565 bbis Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: 730 bbis Total H2O from Duck Lake: 730 bbis Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation: 0 bbis Total Fluid Lost to Hole: 0 bbis 9/18/2018 POOH with retrievamatic packer from 6820' to 6320'. PUW 159K, SOW 115K.;Set packer with COE at 6317'. PT casing to 2500 psi for 30 minutes -good test. Pumped 4.6 bbis with 4.5 bbis returned.;Cut and slip 83' of drilling line, calibrate draw works.;Service rig, grease crown and top drive.;Continue to troubleshoot drawworks communications issues. Replace ODS ethernet switch and configure.;Rig up and FIT to 13 ppg EMW, pressure up to 1000 psi. Rig down test equipment.;Pump dry job. Blow down top drive. POOH from 63lT to surface. L/D test packer. Clean and clear rig floor.;Rig up hawk jaw. Mobilize cleanout BHA components to rig floor. Strap, tally, OD/ID components.;PJSM. M/U cleanout BHA: 8-1/2" bit, bit sub, upper mill, P x P sub, casing scraper, bit sub, (5) HWDP, Jars, (14) HWDP.;Pick up, drift and single in the hole with 5" drill pipe from 634' to 6255' filling pipe every 2500'. Continue to RIH withstands from 6255' to 6949'. PUW 175K, SOW 115K.;Daily Fluid Hauled to MP G&1:135 bbis Total Fluid Hauled to MP G&I: 135 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT: 0 bbis Daily Fluid Hauled to Milne B-50:0 bbis Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: 110bbls Total H2O from Duck Lake: 840 bbis Daily Metal Collected: 0 Lbs Total Metal Collected: 0 Lbs Daily Fluid Lost to Formation, 0 bbls Total Fluid Lost to Hole: 0 bbis 9/19/2018 Continue trip in hole with 8.5" tricone, mill, scraper cleanout assy F/ 6,949'- T/ 7,519' MD (tag 10k, 2x). 189k up,136k dn.;Drill 2' of cmt F/ 7,519' - T/ 7,521' MD. 420 gpm, 785 psi, 53% flow, 60 rpm, 11.4k tq, 1-3k WOB. P/U and circulate 1.5x btms up. 462 gpm, 750 psi w/ 835 units gas @ btms up. Shut do pumps and tag 2x w/ 30k set do @ 7,521' MD.;Monftor well (static). Pump dry job, B/D TDS. POOH F/ 7,521'- T/ surface. B/O and LID cleanout assy. 5 bbl loss for trip out.;M/U Milling assy w/ MWD. Scribe and perform RFO (5761576 = 0°) using MWD to lug orientation on starter mill. RFO = 180° forface of whipstock HS. Shallow pulse test MWD (test good). M/U whipstock assy w/ 3 pins (20k shear) anchor, 45k shear bolt on whipstock.;TIH w/ whipstock assy T/ 3,000' MD filling pipe every2500'. 60 fpm running speed max as per BOT rep. Easy in/out of slips.;TIH w/ whipstock assy from 3,000' MD to 7486' filling pipe every 2500' Picking up working single. 60 fpm running speed max as per BOT rep. Easy in/out of slips. PUW 193K, SOW 133k.;Fill pipe. Establish circulation at 450 gpm/1150 psi. Orientate whipstock 45R. Slack off and tag up at 7524'. Set down 25K to set anchor, pickup and overpull 25K. Set down and shear off with 35K down. Pickup and obtain SPR's and parameters: 500 gpm/1380 psi, 100 rpms/11000 ft -lbs. ROTW 151 K.;Mill window as per Baker from 750V to 7520' and drill 20' of new hole to 7540' with 500 gpm/1360 psi, 100 rpms/12K - 17Kft-lbs, WOM 305K. Work mills through window, no pumps or rotary with no issues.;Pump high viscosity sweep and circulate hole clean 500 gpm11360 psi.;Daily Fluid Hauled to MP G&I:0 bbis Total Fluid Hauled to MP G&I: 135 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT:0 bbls pyl�Lj'pwJ P" Daily Fluid Hauled to Milne 8-50: 0 bible a Total Fluid Hauled to Milne B-50:565 bbls;Daily H2O from Duck Lake: 0 bbls �% ( Total H2O from Duck Lake: 840 bbis Daily Metal Collected: 150 Lbs Total Metal Collected: 150 Lbs Daily Fluid Lost to Formation: 0 bbis Total Fluid Lost to Hole: 0 bbis 9/2 012 01 8 CBU @ 7540' MD. 500 gpm, 1300 psi, 56% flow. Condition mud to 9.65 ppg In/Out. Pump hi vis sweep w/ 10% inc in cuttings. 231# metal final wt for milling window.;P/U to 7486 MD. RIU test equipment. Shut pipe rams and Perform FIT to 12.59 EMW. Psi up 880 psi. Pump 4.7 bbls, bled back 3.1 bbis. Psi stabilized @ 700 psi after 10 min. Chart and record same.;Monitor well (static). Pump dry job, B/D TDS. POOH F/ 7486'- T/ surface. LID mills (in gauge). Hole took proper displacement for trip out.;M/U Johnny whacker and flush stack post milling operations. Clear kill and choke Imes.;M/U 8.5" PDC, 1.5° MTR (6/7 - 6.0 Slg) w/ non ported float. M/U MWD and scribe to mtr. RFO = 597/675 x 360 = 318.4°. Shallow pulse test (test good). Continue TIH F/ 488' - T/ 2003' MD.;Continue to trip in hole with kick off BHA from 2003'to 7439, filling pipe every 2509. Orientate motor to 45R. Obtain SPR's. Slack off through window with no issues. RIH to 7540'. PUW 187K, SOW 134K.;Drill 8-112" hole from 7540'to 7749, sliding as needed to gain separation; 450 gpm/1350 psi off, 1450 psi on bottom, WOE 2-12, 30-50 rpms/12-13Kft-lbs. Max gas 362U. Obtain three clean surveys, 17' of separation from parent wellbore, and rat hole to accommodate RSS assembly.;Pump high viscosity sweep (10% increase) and total of 2 annular volumes 450 gpm/1350 psi standing one stand back to 7691'. Monitorwell, static.;POOH with kickoff assembly from 7691' to 7555'. Orientate motor to 45R continue to POOH through the window with no issues to 7229'. Pump dry job.;Distance from WP07: 14.79', 1.38' low, 14.73' right.;Daily Fluid Hauled to MP G&I: 115 bbls Total Fluid Hauled to MP G&1:250 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT: 0 bbis Daily Fluid Hauled to Milne B-50: 0 bbis Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: 130 bbis Total H2O from Duck Lake: 970 bbis Daily Metal Collected: 81 Lbs Total Metal Collected: 231 Lbs Daily Fluid Lost to Formation: 0 We Total Fluid Lost to Hole: 0 bbis 9/21/2018 Continue to TON f/7245' to 488'. Trip out with calculated hole fill. L/.D BHA V488' as per Sperry Reps. Bit Graded 1-5-BT-S-I-PN-BHA.;Clean and Clear Rig Floor. Stage BHA Components. PJSM on MU BHA.;PU RSS BHA as per Sperry Reps. Up load MWD and pulse test @ 400 gpm. PJSM. Load Nuke Source. MU Remaining BHA.;TIH V483' to7424'MD, PUW 190K, SOW 131K, proper hole displacement.;Slip and cut 63' of drilling line. Service rig, check brake tolerances. Check deadman anchor bolts. Perform derrick inspection.;Grease blocks, crown cluster, top drive and wash pipe.;Continue to RIH from 7424', no issues as bit enters TOW at 7503', observe 3-7K drag through window ramp. Set down 12K at 7542' with Stab (8.4" OD) at top of window. Attempt to work through, attempt to wash through 300 gpm/580 psi, attempt to rotate 1/2 turn and work through. Est. rotary 1-2 rpms.;to work Stab into window. Cont. to RIH, set down 14K at 7594', attempt to work through. Est. circulation at 300 gpm/634 psi and pump in hole, appears to be hole condition with 100-150 psi swing in pump pressure, increase flow to 450gpm/1120 psi at 7612'. At 7637', with MWD tools outside window;establish rotary 40 rpms/11900 ft -lbs and wash and ream to bottom to 7749.;Drill 8- 1/2" from 7749'to 8105'total 350' (AROP = 54fph); initial 80rpms/13.400 ft -Ib until jars exit window, increasing to 140 rpms/13900 ft -lbs, WOE 5-15K, 525 gpm/1520 psi, ECD's 10.3 ppg EMW with 9.7 ppg mud. Max Gas 503U. PUW 205K, SOW 125K, ROTW 163K.;At 8,099'MD, 6408'TVD observe a 200psi increase in pressure. P/U and ream 19, observe pressure increase immediately after touching bottom, no increase in torque/ECD. Ream x3 suspecting Geo - Pilot reference house with same results. Down -link to no deflection, ream 45' (above 8.4" OD stab).;Distance from WP07: 23.34', 2.7' low, 23.18' right.;Daily Fluid Hauled to MP G&1: 58 bbis Total Fluid Hauled to MP G&I: 308 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT: 0 bbis Daily Fluid Hauled to Milne B-50: 0 bbis Total Fluid Hauled to Milne 8-50: 565 bbls;Daily H2O from Duck Lake: 130 bbis Total H2O from Duck Lake: 110 bbis Daily Metal Collected: 55 Lbs Total Metal Collected: 286 Lbs Daily Fluid Lost to Formation: 0 bible Total Fluid Lost to Hole: 0 bbis 9/22/2018 Drill 8.5" F/ 8,105' to 8850" MD. Total 745' (AROP 124 FPH'). 550 GPM. 1700 PSI, 150 RPM, 14.5K TRQ , WOE 10-12K, ECD 10.4 ppg. Max Gas 540u, 9.5 ppg MW. P/U 231 K, SLK 131 K , ROT 164K.;Pump Tandem Sweep @ 8379', back on time with 25% cutting increase.;@ 8850', lost Swab on #1 MP. PU off bottom and Circulate/Reciprocate pipe @ 283 GPM while C/O Liner and Swab.;DnI18.5" F/ 8550'to 8914' MD. Total 364' (AROP 66 FPH'). 550 GPM,1860 PSI, 150 RPM, 17.5K TRQ , WOE 17K, ECD 10.4 ppg. Max Gas 287u, 9.6 ppg MW. P/U 242K, SLK 136K, ROT 172K.;Pump Tandem Sweep @ 8752', 15 bbis late with 10% cutting increase.;Drill 8.5" F/ 8914'to 9196' MD. Total 282' (AROP 94 FPH'). 550 GPM, 1840 PSI, 150 RPM, 19.SK TRQ , WOB 9-15K, ECD 10.45 ppg. Max Gas 342u, 9.6 ppg MW. P/U 253K, SLK 135K , ROT 182K.;Circulate annular volume at 550 gpm/1764 psi, 150 rpms/19,000 ft -lbs; ECD 10.4 ppg EMW.;Wiper trip. BROOH from 9196'to 7825' at 500 gpm, 100 rpms. At 870U start observing small packoffs with increase in torque and pump pressure, adjust running speed as needed to minimize and cleanup. Attempt to pull jars through BOW with no rotary or pumps, with multiple 10-15K overpulls.;Establish pumps at 250 gpm/562 psi. Attempt to rotate 1/2 turn, rotate 1-2 rpms and able to get top of jars through BOW. Attempt to work bump sub through BOW with multiple over pulls of 10K.;RIH to 7930'. Pump high viscosity sweep (9 bbls late, 10% increase) and circulate hole clean at 550 gpm11720 psi, 60 rpms/13,500 ft -lbs reciprocating pipe.;RIH from 7930'to 9196 with no issues. PUW 258, SOW 142K. Proper displacement.;Drill 8.5" F/ 9196to 9385' MD. Total 189' (AROP 76 FPH'). 550 GPM, 1860 PSI, 150 RPM, 19.51K TRQ , WOB 5-15K, ECD 10.58 ppg. Max Gas 202u, 9.6 ppg MW. P/U 260K, SLK 140K, ROT 187K. Pump low vis/high vis tandem sweep at 9322'25% increase in cuttings 25 bbls Iate.;Distance from WP07: 19.41', 19.41' low, 0.53' right.;Daily Fluid Hauled to MP G&I: 404 bbls Total Fluid Hauled to MP G&I: 712 bbis Daily Fluid Hauled to ORT: 0 bbis Total Fluid Hauled to ORT:0 bbis Daily Fluid Hauled to Milne B-50: 0 bbls Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: 600 bbls Total H2O from Duck Lake: 1700 bbls Daily Metal Collected: 20 Lbs Total Metal Collected: 306 Lbs Daily Fluid Lost to Formation:0 bbls Total Fluid Lost to Hole: 0 bbls 9/23/2018 Drill 8.5" F/ 9385' to 9675' MD. Total 290' (AROP 48 FPH') 550 GPM, 1950 PSI, 150 RPM, 21 K TRQ , WOB 14K, ECD 10.5 ppg. Max Gas 202u, 9.6 ppg MW PN 275K, SLK 138K, ROT 190K.;Start adding lube to 2% to mitigate TQ.;Drill 8.5" F/ 9675'to 9922' MD. Total 247' (AROP 45 FPH') 550 GPM, 2130 PSI, 150 RPM, 22K TRQ , WOB 21 K, ECD 10.53 ppg. Max Gas 46u, 9.6 ppg MW P/U 291 K, SLK 139K, ROT 193K. Continue to add lubes up to 3% v/v to mitigate torque.;Circulate and reciprocate pipe while changing out MP 1 pod 4 wear plate.;Drill 8.5" F/ 9922'to 10,260' MD. Total 338' (AROP 56 FPH') 550 GPM, 2140 PSI, 150 RPM, 23K TRQ , WOB 10-14K, ECD 10.48 ppg. Max Gas 71 u, 9.6 ppg MW P/U 295K, SLK 145K, ROT 200K.;Drill 8.5" F/ 10260' to 10,628' MD. Total 368' (AROP 61 FPH') 550 GPM, 2140 PSI, 150 RPM, 22K TRQ , WOB 12-15K, ECD 10.55 ppg. Malt Gas 1624u, 9.6 ppg MW P/U 286K, SLK 156K, ROT 206K. Pump tandem to vis/high vis sweep at 10,267' wfth 25% increase in cuttings, 21 bbis Iate.;Distance from WP07: 2.41' , 1.93' High, 1.45' Right.;Daily Fluid Hauled to MP G&I: 346 bbls Total Fluid Hauled to MP G&I: 1058 bbls Daily Fluid Hauled to ORT:0 bbls Total Fluid Hauled to ORT: 0 bbls Daily Fluid Hauled to Milne B-50: 0 bbls Total Fluid Hauled to Milne B-50: 565 bbls;Daily H2O from Duck Lake: 380 bbis Total H2O from Duck Lake: 2080 bbls Daily Metal Collected: 52 Lbs Total Metal Collected: 3581-bs Daily Fluid Lost to Formation: 0 bbls 9/24/2018 Drill 8.5" F/ 10,628'to 10,708' MD. Total 80' (AROP 53 FPH') 550 GPM, 2140 PSI, 150 RPM, 22K TRQ , WOB 14K, ECD 10.55 ppg. Max Gas 695u, 9.6 ppg MW P/U 285K, SLK 160K, ROT 208K.;CBU @ drilling rate prior to Wiper Trip. 550 gpm/2100psi, 120 rpm/21.5K Tq. Monitor well. Well Static.;POOH on elevators from 10,708'to 9225'. Encounter several 15-20K Over pulls. Wipe Clean with no issues. PUW 295k, SOW 168K. Hole took calculated displacement;CBU working pipe from 9225' to 9155'. 500 gpm/1700 psi, 120 rpm/17.5 Tq. Max Gas @ 58u. WOO from Drilling Team in town Before Tripping back to Bottom. Decision made to shorten TO and drill to 10,900' casing point. Logs showed Hydro Carbon Zone @ 10,393'.;TIH on elevators from 9225' to 10,606' with no issues. Wash last stand to bottom with no fill. See 4400 units gas @ B/U. Load Tandem Sweep in pipe.;Drill 8.5" F/ 10,708' to 10,898' MD. Total 190' (AROP 76 FPH') (8112" Hole Section TD) 550 GPM, 2220 PSI, 150 RPM, 24K TRQ , WOB 16K, ECD 10.55 ppg. Max Gas 425u, 9.6 ppg MW P/U 282K, SLK 162K , ROT 208K. Sweep back 15 bbls late with 75% increase cutting back.;CBU from 10,898'@ drilling parameters. Rack back 1 stand and circulate additional BN 550 gpM2060 psi, monitor well, static.;POOH from 10,835'to 9356'MD with no issues, proper hole fill. PUW 254K, SOW 157K. Cementing equipment confirmed sourced for two stage job, decision to continue drilling to planned TO 12,092'.;RIH from 9356'to 10,898', washing last stand to bottom. Proper displacement. PUW 298K, SOW 160K.;Circulate and condition mud for HRZ, weighing up to 10.3 ppg and increasing Baracarb concentration to 20 ppb, Baratrol/BaraFLC up to 4 ppb and 3% v/v GEM GP.;Driil 8.5"F/ 10,898' to 11,244 MD. Total 346' (AROP 69 FPH') 525 GPM, 2180 PSI, 150 RPM, 21 K TRQ , WOB 9-13K, ECD 11.18ppg. Max Gas 897u, 10.3 ppg MW P/U 266K, SLK 178K, ROT 216K.;Distance from WP07: 3.41' , 1.22' Low, 3.19' Right.;Hauled 636 Fluid to MP G&I total =1694 bbls Hauled 0 bbls fluid to ORT total = 0 bbls Hauled 0 bbls fluid to Milne B-50 total = 565 bbis Hauled 390 bbls H2O from Duck Lake total = 2470 bbls Collected 35 lbs metal total = 393 lbs Lost 0 bbls to formation for total= 0 bbls 9/25/2018 Drill 8.5" F/ 11,244'to 11,278" MD. Total 34' (AROP 34' FPH) 550 GPM, 2180 PSI, 150 RPM, 22.51K TRQ , WOB 14-22K, ECD 11.3ppg. Max Gas 486u, 10.3 ppg MW P/U 266K, SLK 178K, ROT 217K.;Observed losses to hole while drilling @ 11,270'(+- Top of LCU/TITK). Confirmed @ connection with pumps off. Fluid dropped below wellhead.;BROOH slowly from 11,278'to 11,146 @ 50 rpm/125 gpm/550 SPP. Begin Mixing LCM PiII.;TOH above HRZ on elevators from 11,146 to 10,995' encounter 2 25K over pulls and wipe clean with no issues. PU 290K, SO 180K. Lost 25 bbls pulling above HRZ.;Circulate/Rotate/Reciprocate pipe from 10,888 to 10,995' while mixing 50 ppb LCM Pill. Increase back ground LCM in Active volume from 20 ppb to 40 ppb. Pump 26 bbls LCM Pill and spot pill in Annulus @ 125 gpm/335 SPP, 50 rpm. Initial loss rate @ 87 BPH.;POOH above pill on elevators with no issues f/10,888' to 10,585'. Lost 23 bbls pulling out of pill. P/U 285K, S/O 175K.;Circulate above LCM pill staging pump from 125 gpm to 550 gpm. Initial loss rete at start of circulation @ 56 bph, diminishing to 0 BPH.;TIH on elevators 1/10,585'to 11,217'@ 8-10 fpm through HRZ with no hole issues. Wash last stand to bottom @ 11,278' with no issues.;Drill 8.5" F/ 11,278'to 11,469' MD. Total 191' (AROP 34' FPH) 500 GPM, 2000 PSI, 100 RPM, 23.5K TRQ , WOB 22K, ECD 11.0ppg. Max Gas 592u, 10.3 ppg MW P/U 292K, SLK 181K, ROT 223K. Pump LCM pill at 11,406', observe losses decrease from 20 bph to 5 bph.;Drill 8.5" F/ 11,469' to 11,719' MD. Total 250' (AROP 42' FPH) 500 GPM, 1915 PSI, 120 RPM, 23.5K TRQ , WOB 10-14K, ECD 11.0ppg. Max Gas 64u, 10.3 ppg MW P/U 303K, SLK 182K, ROT 225K. Observe 20 bph losses at 11530', pump 25 bbls LCM pill at 11,530' and 11,594' with losses decreasing to 5bph.;Drill 8.5" F/ 11,719to 12,000' MD. Total 281' (AROP 47' FPH) 500 GPM, 2036 PSI, 120 RPM, 24.3K TRQ , WOB 9-12K, ECD 11.07ppg. Max Gas 1348u, 10.3 ppg MW PN 31 OK, SLK 184K, ROT 236K.;Oistance from WP07: 7.02', 1.25' High, 6.9' Right.;Hauled 229 Fluid to MP G&I total = 1923 bbls Hauled 0 bbls fluid to ORT total = 0 bbls Hauled 0 bbls fluid to Milne B-50 total = 565 bbls Hauled 290 bbls H2O from Duck Lake total = 2990 bbls Collected 33 lbs metal total = 426 Its Lost 376 bbls to formation for total= 376 bbls 9/26/2018 Drill 8.5" F/ 12,009 to 12 193' MD. Total' (AROP 43' FPH) 500 GPM, 2036 PSI, 120 RPM, 25.5K TRQ , WOB 20K, ECD 11.07ppg. Max Gas 1192u, 10.3 ppg MW P/U 322K, SLK 188K , ROT 241 K.;Ave loss rate while drilling = 17 bph/Lost 85 bbls from 12000'-12193'.;Pump hi vis sweep and circulate clean. Losses Rate @ 34 bph while bringing first sweep to surface. Pump 2nd Sweep with 40 ppb Steel Seal and circulate hole clean, with losses falling to 11 bph.;POOH on Elevators to 10,964' above HRZ. No issues pulling to 10,964'. Losses @ 4 bph static.;TIH on elevators from 10,964' TD washing last stand to bottom. No fill on Bottom. No issues on TIH.;Pump Sweep and Circulate hole clean 500 gpm/1975 psi, 100 rpms/20K-ftlbs Reciprocating pipe. Sweep 9 bbls late 10% increase in cuttings. Monitor well static. Spot 95 bible liner running fluid in annulus up to HRZ.;POOH from 12,193! to 10,895' above liner running pill. With no issues PUW 280K, SOW 172K.;Spot 25 bbls LCM pill in annulus, 465 gpm/1718 psi. Monitor well, static.;Continue to POOH from 10,895' to 9162'. Wipe two tight spots clean at 10,472' (30K over x 3), and 10,435'(25K over). Attempt to wipe tight spot at 9162' pulling up to 40K, slacking off 25K, unable to wipe clean. Slack off to 9185' and establish circulation and rotary.;Back ream out of hole from 9185' to 8566' at 500 gpm/1750 psi, 100 rpms erratic torque from 14500ft-lbs up to 20000 ft -lbs (stall). From 9162'to 9000' pulling speed 1-3 fpm due to high erratic torque and slight packoffs. Pump high vis sweep at 9000' 25% increase. Hole cleaning up at 9000',;with 100 rpms/12,000 ft -lbs, 500 gpm/1680psi. PUW 220, SOW 145K, ROTW 162K.;Distance from WP07: 4.75' , 0.54' High, 4.72' Right.;Hauled 173 Fluid to MP G&I total = 2096 bbls Hauled 0 bbls fluid to ORT total = 0 bbls Hauled 0 bbls fluid to Milne B-50 total = 565 bbls Hauled 260 bbls H2O from Duck Lake total = 3250 bbls Collected 20 lbs metal total = 446 lbs Lost 203 bbls to formation for total= 579 bbls 9127/2018 Continue to BROOH From 8566' to 7870'@ 500 gpm/1700 SPP, 100 rpm/12K Tq. No issues BROOH to 7870'. Lost 15 bbls while BROOH from 8566'/7.5 BPH Loss Rate.;CBU working pipe from 7870' to 7850' @ 550 gpm/1970 psi, 60 rpm/8K Tq. No substantial increase in cuttings observed. P/U 205K, S/O 140K.;Attempt to POOH on Elevators from 7850', with Jars at Btm of window @ 7520'. Encounter 10-15 over pulls. Attempt several times to work Jars through window rocking pipe with no success. Bring on pump and rotary and work jars/bumper sub through window @ 2-5 rpm/42 gpm.;With Jars/Bumper Sub above window and HWDP across window, POOH on elevators 1 std to 7745' w/no issues. See 10-15K over pull on next std. BROOH 7550'to 7492'@ 500 gpm/15-25 rpm/9-13k Tq. See multiple Pack offs/stalls. POOH on elevators from 7492' bringing Bit through TOW @ 7500'.;TIH to 7550' running bit through windowwith no issues. POOH above window 2nd time with and pull through clean.;Pump 35 bbls 12.3 ppg slug, blow down Top Drive and Geo Span.;POOH on elevators from 7500'to 172' racking back DP, HWDP, and DC. Loss rate 10 bph.;Lay down BHA. Unload sources. Download MWD data from tools. Minimal scarring noted on BHA. Bit Grade 1-1-CT-N-I-X-NO-TD. Clean and clear rig floor. Loss rate 10 bph.;Pick up Clean Out BHA, 8.5" tricone bit, bit sub, (2) NM DC, (10) HWDP, Jars, (5) HWDP.;RIH with cleanout assembly to 7442' filling pipe every 2500'. PUW 100K, SOW 95K. Lost 17 bbls during trip.;Circulate annular volume priorto going through window at 550 gpm/1415 psi. No Iosses.;Continue to RIH from 7442'to 9650'. Set down 12K x 2 while bitgoes into top of window. Pickup and put 1/4 turn in string and work several times setting down. Continue to RIH with no issues. PUW 225K, SOW 155K. Loss rate 5 bph.;Hauled 58 Fluid to MP G&I total= 2154 bbls Hauled 0 bbls fluid to ORT total = 0 bbls Hauled 0 bbls fluid to Milne B-50 total = 565 bible Hauled 0 bbls H2O from Duck Lake total = 3250 bbls Collected 5 lbs metal total = 451 lbs Lost 126 bbls to formation for total= 705 bbls 9/28/2018 Continue to TIH on elevators f/9842'to 10,914' wlout issues. P/U 270K, SO 160K.;Sweep and circulate hole clean above HRZ f/10,914' 2 600 gpm/1650 psi, 100 rpm/16.51K Tq, Rot 225K.;Conbnus to TIH with no issues to through HRZ @ 10-15 fpm. Seen set 1 OK Set down @ 12,060'.;Stage pumps slowly to 500 gpm/1675 psi, 100 rpm/21.8K Tq. Wash and Ream f/ 12,060 to TO @ 12,193'. P/U311 K, SO 180K, Rot 266K. Did see 10-14K WOB at times.;Circ B/U @ 550 gpm/1870 psi, 100 rpm/21.4K To. Max gas @ 244u. Pump 25 bbls hi vis sweep with 40 ppb LCM. Back on time with 100% increase Cuttings and LCM. Pump and Spot 88 bbls liner running pill from 12,193'to above HRZ @ 10,900'.;P00H on elevators f/12,193'to 10,850'. No issues pulling to 10, 850'. P/U 280K, SO 180K.;Pump and spot 30 bbls LCM Pill w/ Baracarbs only and no steel seal f/10,850.;P00H on elevator f/10,850'to 10,220'. (above LCM pill) and monitor well on TT f/ 15 min. w/10 bph static loss rate.;Continue to POOH on elevators from 10,229to 7411' with no issues. No issues pulling jars or bit through window. PUW 180K, SOW 132K.;Circulate annular volume at 465 gpm/1020 psi. Loss rate 14 bph.;Slip and cut 132' of drilling line while monitoring on trip tank. Loss rate 13 bph ;Service rig. Grease top drive, blocks, crown, and spinnem.;Continue to POOH on elevators from 7411'to surface. L/D drill collars, HWDP, jars. Loss rate 13 bph.;Rig up hose to keep annulus full. Pull wear ring. Set test plug. C/O UPR to 7".;Hauled 58 Fluid to MP G&I total = 2212 bbls Hauled 0 bbls fluid to ORT total = 0 bbls Hauled 0 bbls fluid to Milne B-0 total = 565 bbls Hauled 0 bbls H2O from Duck Lake total = 3250 bbls Collected O lbs metal total = 451 lbs Lost 206 bbls to formation for total= 911 bbls UHill Energy Company Composite Report Well Name: END 266A Field: Endicott County/State: , Alaska (LAT/LONG): ovation (RKB): API #: Spud Date: Job Name: 1811485C END 266A Completion Contractor Innovation AFE #: AFE $: Acttvity Date Ops Summary 9/29/2018 Continue to change out UPR's to 7" solid bodies.,Set test plug. RILDS. R/U and test UPRs and annular on 7" test joint to 250/5000 psi. Good. R/D test equipment. Pull test plug. Set wear bushing.,Rig up to RIH with 7" 26# DWC/C liner. R/U Weatherford power tongs. C/O elevators to 7" side doors.,M/U shoe track and Bakerl-ok. Check floats. RIH with 7" 26# DWC/C liner from surface to 3392' fill pipe on the fly and top off every 10 joints. Break circulation every 20 joints.,Continue to RIH with 7" 26# DWC/C liner from 3392' to 5863' fill pipe on the fly and top off every 10 joints. Break circulation every 20 joints. Fill last 5 with new no LCM mud.,Change out pipe handling equipment, swap elevators. Pickup Baker Liner top packer and hanger. Install Halliburton cementing darts. Fill Liner top packer void with Xanplex and let set. Rig down Weatherford power tongs. Rig up to drift out of derrick. PUW142K SOW 107k. Obtain static loss rate of 11 bph.,Continue to RIH with 7" liner on drill pipe from 5863' to 7470', drifting out of derrick. Observe flow out % drop while running in hole. Loss rate first 5 stands 20 bph. Slow max running speed down to 30 fpm with easy out of slips for -15', loss rate slowing to 11-13 bph. Fill pipe on the fly topping off every 10 stands.,Establish circulation and stage pumps up to from 2 bpm/290psi, 3bpm/320psi, 4bpm/370 psi, 5bpm ICP 435 psi FCP 370 psi. 10 rpms/9000 ft -lbs, 20 rpms/9200 ft -lbs. PUW 182K. SOW 142K, ROTW 140K. Circulate annular volume at 5 bpm, loss rate at 5 bpm 15 bph.,Continue to RIH with 7" liner on drill pipe from 7470' to 8350', max running 30 fpm easy in and out of slips. Filling pipe on the fly topping off every 10 stands.,Hauled 0 Fluid to MP G&I total = 2212 bbls Hauled 0 bbis fluid to ORT total = 0 bbls Hauled 0 bbis fluid to Milne B-0 total = 565 bbis Hauled 130 bbls H2O from Duck Lake total = 3380 We Collected 4 Ibs metal total = 455 lbs Lost 276.3 We to formation for toital= 1187.3 bbl 9/30/2018 Continue to RIH w/7" liner on 5" DP f/8350'- 10,630'A 20 fpm max running speed. Drift pipe in Derrick w/3.13" OD Drift. P/U 250K, S/O146K. Loss rate @ 15 bph while running pipe.,CSU X 2 prior to entering HRZ. Stage pumps to 7 bpm/650 psi. Recip pipe 61 PIU 245-285K, S/O 150K. Max gas @ 162u.,Continue to RIH wl7" liner on 5" DP f/10,630' - 12.149'@ 15 fpm max running speed. Wash last stand to bottom @ 12,186'. Obtain PIU Wt to 280K Had to pull 150K over before break over. Atttempt to work pipe. Pulling tight and see signs of packing off. Park @ 12,183'.,CBU from12,183', staging pump from 3 bpm to 4 bpm/800 psi. Attempt 4.5 bpm and see signs of packing off. Drop flow rate back to 4 bpm/810 psi. Shut down Pump and R/U BOT CMT Swivel/Dual plug drop head.,Re-establish circulation staging pumps up to 4 bpm/650 psi. Finish rigging up for cement job. PJSM.,Cement as per detail. Halliburton pump cl'tll5 bbls of water to flush lines. Shut down and PT lines 1000/5000 psi - good. Pump 33 bbis 10.5 prig clean spacer at 2.7 bph/460 psi 30 bbis 14.5 prig tt Premium G cement at 2.6 bpm/381 psi. Drop dart. Displace with 20 bbis water at 4 bpm/580 psi. Shut down and hand over to rig. Rig displaced and bumped plug with 304.6 bola (306.6 calc) 10.3ppg.,drilling fluid initial rate 4 bpm 582 psi. At 1361 strokes (1391 calculated)observe pressure increase to 1230 as dart latches up and releases plug. With 25 bibles to go as cement just rounds the comer Slow rate down to 2 bpm/548psi bump plug with FCP 662 psi, pressure up to 1150 psi and held for five minutes. Check floats good.,Lost 6 bbis during pumping cement and 31 bbls while displacing. CIP at 22:06hm.,Pressure up to 2250 psi and shift open ES cementer Circulate hole at 4 bpm/600 psi with 2bph loss rate. Slight pH increase just prior to bottoms up to 11.4, no other indication of spacer. WOC. PJSM for second stage.,Cement as per detail. Halliburton pump 5 bible to flush lines. PT lines 100015000 psi - good. Pump 33 bbls of 10.5 ppg Clean Spacer at 2.8 bpm/462 psi, 23 bbls 15.8ppg Class G cement 2.8 bpm/520 psi, Drop dart. Displace with 20 bbis water at 4 bpm/460 psi. Shut down turn over to rig. Rig displaced with 10.3 ppg drilling fluid at 5 bpm/620 psi: 124 bbls into displacement (249 calculated) at report time. No losses -Hauled 182 Fluid to MP G&I total = 2394 bbis Hauled 0 bbls fluid to ORT total = 0 bible L Hauled 0 bbis fluid to Milne B-0 total = 565 bbls l Hauled 260 bbls H2O from Duck Lake total = 3640 bbis 5" Collected 0 be metal total = 455 lbs Lost 291.2 bbis to formation for total= 1478.5 bbls 10/1/2018 Continue displacing 2nd stage cement with 10.3 ppg drilling fluid at 5bpm. Slow to 3 bpm with 20 bbis left in displacement. Bump plug at 247.5 bbls (249 bible calculated) FCP 800 psi. CIP at 06:30. Pressure up to 2500 psi and hold for five minutes to close ES cementer. Check for flow to ensure closed - good.,HES pressure up to 2900 psi and set Hanger. SIO f/250K 10 70K and confirm set. Pressure to 4200 psi and set LTP. PIU & confirm Set. Bleed pressure off. Rig pressure up to PT IA. Pack off on running tool failed when reaching 3000 psi. Confirm by bleeding down DP Pressure and CSG Pressure dropped as well. Bleed down and R/D CMT Head., Unsling from PKR, Drop Wiper ball, pump wiper ball around @ 550 gpm/370 psi. Monitor well. Pump Slug -POOH UD 5" DP from 6250'. Inspect and UD Liner running tool. Pack off was damaged. Dog Sub sheared.,Semice Rig.,MN Wear Bushing running tool and retrieve wear bushing. UD running tool.,Set Test Plug, RILDS, M/U Test Test tool on TD, MW Pump in sub, TIW & Dart onto Test Jt.,C/O UPR's f/7" back to 2 7/8" x 51/2 VBR's. Rig up to test BOPE. Flood lines and purge air.,Test all BOPE components on 3-1/2" and 5" drill pipe 250/4000 psi. AOGCC right to witness test waived by Matt Herrera. Test all gas alarms. Accumulator test 6 N2 @2250 average, starting pressure 3000 psi, final 1500 psi. 200 psi recharge 25 seconds, full recharge 95 seconds.,Lay down test tool, Rid test equipment. Blow down choke and kill Iines.,Pick up and make up BHA: 6-1/8" mill tooth bit, bit sub with solid float, (10) joints 4" HT38 HWDP. Pick up, drift and single in the hole with 4" drill pipe to 3169'.,Hauled 1041 Fluid to MP G&I total = 4277 bbis Hauled 0 bbis fluid to ORT total = 0 bbis Hauled 0 bbis fluid to Milne B-0 total = 565 bbls Hauled 130 bbis H2O from Duck Lake total = 3870 bbls Collected 0 Itis metal total = 455 Ibs Lost 3 bole to formation for total= 1481.5 bbls 10/2/2018 Cont TIH P/U and drift T' DP f/3196' to 6280' P/U 108K, S/O 84K. C/O Elevator Inserts to 5".,RIH with 5" DP out of Derrick 1/6280' U10 510'- Wash down and Tag w/no Rotary @ 10,544'. Circulate Drill string volume @ 400 gpm/2070 psi, 60 rpm/11 KTq.,Drill Drill plugs and CMTR f/10,544' w/350-400 gpm/1670-2070 psi,60 rpm/12K Tq, 815 wob. Wash and Ream CMTR X 2.. Make Dry Pass with no issues .PIU 255K, SO 148K.,Continue to TIH f/10553 to11960'. Wash down w/no rotary and Tag hard CMT @ 12,015'. Set Dn 15K., Drill hard CMT f/ 12,015" to 12,057'( Top of Bfl Adapt) w/350 gpm/1800 psi, 80 rpm/16-18K Tq, 5-6 web. PIU 255K, SO 148K, Rot 188K.,CBU from 12,057' @ 400 gpm/2215 psi, 80 rpm/16K.,R/U and test casing to 3000 psi for 30 minutes -good, Rig down test equipment. Grease choke kill valves. Blow down choke Iines., Displace well to seawater. Pump 45 bbls high viscosity spacer followed by 870 bbis seawater at 5.5 bpm/690 psi, max rate vac trucks were able to supply mud pumps.,Clean under shakers, trough, flowline. Offload drilling fluid from pits. Prep for 9.0 ppg 3% KCL displacement.,Displace well from seawater to 9.0 ppg 3% KCL at 6bpm/800psi, pump 660 bbis from vac truck.,Weigh up brine from 9.0 ppg to 9.4 ppg at 11 bpm/3190 psi.,POOH with casing cleanout assembly from 12045' to 9249'.,Hauled 1041 Fluid to MP G&I total = 4277 bbls Hauled 0 bible fluid to ORT total = 0 bbls Hauled 0 bbis fluid to Milne B-0 total = 565 bbls Hauled 130 bels H2O from Duck Lake total = 3870 bbis Collected 0lbs metal total = 455 lbs Lost 3 bbis to formation for total= 1481.5 bbis 10/3/2018 Continue POOH f/9249' U 302'. Did not see anything pulling through TOL. Rack back 4" HWDP. LID Bit and Bit sub.,Pull riser, remove hole fill line, N/D bell nipple set on floor in cellar. PIU shooting flange & install on top of Bag. SIMOPS: Cleaning pits.,R/U Pollard E -Line and Halliburton to Run CASTM CBL.,Pollard RIH with HES CASTM Logging Tools. Log from 12,050' to 8800'.,Rig up lubricator. Build prep perf gun. CBL logs being processed by HES.,Make up tool string through lubricator. Attempt to lest pack -off leaking. Change out pack off.,RIH with 3-3/8" 25 gram 6 SPF pert guns. Correlate on depth and confirm with town. Perforate from 10,395' to 10,405'. Initial slight vac on hole, fill through kill line no losses. Rig down tool string and Iubricator.,N/D shooting flange, NIU riser. Continue to monitor well.,Hauted 1374 Fluid to MP G&I total = 5651 bbls Hauled 0 bbis fluid to ORT total = 0 bels Hauled 0 bbis fluid to Milne B-0 total = 565 bels Hauled 260 bbis H2O from Duck Lake total = 4130 bbis Collected 0lbs metal total = 455 Ibs lost 0 bels to formation for total= 1481.5 bels 10/4/2018 Open Blind Rams, blow down choke manifold and lines. RIH W/ 6 118" Tri Cone Bit, 7" Scrapper, Float Sub, X/O, 10 Jnts 5" HWDP, 5,976' 4.5" D.P. and 5" D.P. to 12,030' MD. Filling every 3,000'.,Wash down to 12,05T, tag 10K. Pump 25 bbl Hi Vis sweep at 500 GPM, 3,350 PSI. Monitor well for 10 Min, static. Pump dry job. Blow down Top DrIve.,POOH laying down 5" D.P. FI 12,057' to 9,254' MD. P/U 190K, SLK 125K. Observed proper hole fill.,PJSM for laying down D.P. P/U and R/U Hawk Jaw. Cont. laying down 5" D.P. F/ 9,254' to 6,349' MD. PIU 115K, SLK 85K. Correct hole fill., PJSM Slip and cut drilling line. 132' of line. Calibrate blocks.,RIH 5" D.P. F/ 6,349'to 7,264' MD., LID 5" D.P. F/ 7,264' to 6,286' MD.,C/O Elevators F/ 5" to 4". Prep floor to lay down 4" D.P. HT38. Grease Top Drive, Crown, Spinners and inspect Equip. Monitor well on trip tank, no Iosses.,Lay down 4" D.P. to Pipe Shed F/ 6,286'to 310' MD. P/U 40K, SLK 40K. Lay down HWDP, Scrapper and Bit. Proper hole fill for trip., Pull Wear Ring and lay down.,R/D LID Hawk Jaw. RID Elevators. Prep and stage jewelry in Pipe Shed.,PJSM RIU Weatherford tools and Equip.,Hauled 114 bbis Fluid to MP G&I total = 5765 bbis Hauled 0 bels fluid to ORT total = 0 bels Hauled 0 bels fluid to Milne B-0 total = 565 bbis Hauled 0 bbis H2O from Duck Lake total = 4130 bbis Collected 0 Iles metal total = 455 lbs lost 0 bels to formation for total= 1481.5 blots 10/5/2018 Finish rigging up Weatherford torque turn Equip. and test. PJSM on running completion.,RIH w/3.5", 9.3# 13CR, JFE BEAR Tbg and Jewelry as per tally detail. Drift w/2.867" OD. Run 95 jts. Discover discrepancy in Torque tum Graph. Inspect connection. Pin end ok, slight flaring of Seal area in box. POOH LID 6 jts. Inspecting same. Kick out Jts 90,91,92 & 94. Consult with JFE BAER Rep. Lower Tq on tubing from 5800 ft/lbs to 4500 ft/lbs. Continue to RIH P/U Completion to 4,140' MD.,Continue RIH w/3.5", 9.3# 13CR, JFE BEAR Tbg and Jewelry as per tally detail. Drift w/2.867" OD F/ 4,140' to 10,065' MD. P/U 107K, SLK 78K.,PJSM for SLB SSSV. M/U SSSV. Hang sheave, set spooler and M/U SS line to SSSV. Purge and test for 15 Min.,Continue RIH w/3.5", 9.3# 13CR, JFE BEAR Tbg and Jewelry as per tally detail. Drift w/2.867" OD F/ 10,065'to 11,569' MD. PIU 120K, SLK 88K.,Clear rig floor for Slcikline. R/U Pollard Slickline-Hauled 0 bels Fluid to MP G&I total = 5765 bbis Hauled 0 bets fluid to ORT total = 0 bbis Hauled 0 bels fluid to Milne B-0 total = 565 bbls Hauled 0 bbis H2O from Duck Lake total = 4130 bbis Collected 0 lbs metal total = 455 lbs lost 0 bbis to formation for total= 1481.5 bbls 10/6/2018 R/U Pollard Slick Line and RIH w/2.77" GR to 11544' WLM. (Top of XN Nipple @ 11,556 Tally Depth) POOH and LID Slick Une.,C/O Elevators to 5" DP. P/U and WU Tbg Hgr to string. RID Weatherford Tong equipment. M/U Landing JT. SLB Dress control lines. Test Control lines to 5150 psi.,RIH & park 2' above Tbg Head with Hanger. Pump 398 bbis of Corrosion inhibited 9.4 ppg brine.@ 2 bpm/145 psi/3 bpm/315 psi. Chase and spot with 9.4 ppg brine.,Drain Stack. Land Tbg Hgr. RILDS. Drop 1.3125 ball and rod. R/U test equipment while ball falling.,Attempt to test tubing. See IA Pressure Up. Bleed down Pressure. Line up to see returns @ cellar. Pump Dn Tbg and see returns @ Cellar. RID test Equipment.,R/U Pollard Slick Line. RIH with Slick line w/2.7T' Gauge Ring and Knuckle Jts, Set down @ 6977' WLM.( Station 5 GLM @ 6971 Tally Measurement) POOH and PU SB Pulling tool„PJSM RIH W/ 2” S.B. pulling tool. RIH to retrieve rod and ball, did not tag at 6,977' SLI. Decision was made to chase ball and rod to RHC -M. POOH at 11,500' SLM. At surface observed only 3 weight bars. Knuckle, Spang, Oil Jars and latch left in hole. C/O to retrieval latch and RIH. Tag fish at 11,574' SLI. POOL W/ tools.,PJSM R/U testing Equip. Test 3.5" Tubing to 3,000 PSI for 30 Min. monitor IA. Bleed down tubing to 1,500 PSI. Press. up IA to 3,000 PSI for 30 Min testing upper Packer. Bleed down IA and 3.5" Tubing. All charted and witnessed by Co Rep.,PJSM RIH W/ 2" S.B. running tools to 11,568' SLM. Retrieve Ball and Rod. POOH LID Pollard tools and Equip. Decision was made to leave RHC -M for later slickline operations by operations.,PJSM Pressure up 3.5" Tubing to test lower Packer to 3 000 PSI for 30 Min. Bleed down tubing to 1,500 PSI, Press up IA to 3,000 PSI and dump tubing Press. to shear GLM valve. Both IA and tubing bled to zero. all charted and witnessed by Co Rep. Pump down IA and tubing at 2 bpm to ensure shear valve was open.,N/D BOPE and set back.,Prep Hanger neck, terminate control line, set adapter flange and Tree. WU and torque as per NOS Rep onsite. Fill and test to 250 PSI low for 5 Min. SIMOPS unpin BOP cradle platform. 10/7/2018 PJSM. Well Head Rep test void t/5000 psi. Pull BPV, Set TWC,PT Dry hole tree to 5000 psi. Pull TWC. SLB Open SSSV. SIMOPS: Finish cleaning pits. Prep MP 1 & 2 for rig move. Remove Sub Floor and weld Pad Eye.,R/U LRS and pump 92 bbls DSL FP down IA @ 2 bpm 550 psi. RID LRS. Line up well to U - Tube. Prep floor and Bridle Up. Cont prepping MP's. Prep Cellar for rig Move.,PJSM, Scope Down Derrick, RID Geronimo Line.,R/D Mezz Mud Lines, Crane Sperry Shack and tool box oft Roof Top. Close SSSV. Set TWC, RID U -Tube Lines. Swap Rig to Gen Power., Disconnect Plug Boards. Between Mods. RID Pipe shed, RID Break Shack/Envirovac spot out f way. Blow down Steam/Water, Prep roof Top, C/O DS Tong hang line, finish loading total of 448 its 5 DP & process same. Pull Hi line Power to next well., Disconnect service lines. Move and spot Pit Mod, Motor Mod, Catwalk and Sub. Crane adapter spools.,Lay Herculite and Matt Boards on 2-50. Move Sub to 2-50. Crane off Well House. Spot Sub over 2-50. 10/12/2018 "'WELL SHUT IN UPON DEPARTURE"' (post RWO) "PT PCE 25O#-LOW/3,509#-HIGH" DAMAGE WIRE IN TRSSSV, LAY DOWN, PULL AND CUT AT DAMGED SECTION, 7500' OF WIRE PULL 1-1/2" SHEAR VALVE IN STA#6 @ 4077' SLM (4095' MD) PULL 1-1/2" DGLV IN STA #4 @ 8292' SLM (8294' MD) PULL 1-1/2" DGLV IN STA #5 @ 6965' SLM (6970' MD) WELL SHUT IN UPON DEPARTURE "CONTINUE JOB ON 10-13-18 WSR" 10/13/2018 "'CONTINUE JOB FROM 10-12-18 WSR, WELL SHUT IN UPON DEPARTURE"' "PT PCE 300#-LOW/3,500#-HIGH" SET NEW GASLIFT DESIGN IN STA'S *6,5, & 4 PULL RHC PLUG BODY FROM XN NIP @ 11545' SLM (11554' MD), UP TO PAKER @ 10311' MD DROP CUTTER BAR, QC, 61-7/8 ROLLER STEM (2.2 WLS), 1-7/8" SHORTY GO -DEVIL CUTTER (RECOVERED ALL WIRE) PULL CUTTER BAR @ 10294' SLM "CONTINUE JOB ON 10-14-18 WSR" 10/14/2018 "'CONTINUE FROM 10/13/18 WSR, WELL SHUT IN ON ARRIVAL"' "PT PCE 2509-LOW/3,5009-HIGH" SWAP UNIT FROM SLICKLINE TO BRAIDED LINE FISH TOOL STRING @ 10288' BLM PULL 3.5" RHC PLUG BODY @ 10307' BLM (MARKS ON KEY HOUSING OF WHAT APPEARS TO BE AN OVER TORQUED COLLAR) SWAP UNIT BACK TO SLICKLINE FROM BRAIDED LINE "CONTINUE JOB ON 10-15-18" 1011512018 "'"CONTINUE FROM 10/13/18 WSR, WELL SHUT IN ON ARRIVAL"' "PT PCE 300#-LOW/3,5009-HIGH" DRIFT TBG FOR PERF GUNS W/ 2.68 CENT, 20'x 2.50" BAILER. Tag T/D @ 12037' SLM SHIFT SLIDING SLEEVE OPEN (DOWN) @ 10361' SLM (10363' MD) SET 3 1/2" (2.813") X LOCK, FLOW THRU SUB,TANDEM SPARTEK GAUGES IN X NIP @ 10269' SLM (10270' MD) (START TIME ON GAUGES 10/15/18 @ 13:29) "JOB COMPLETE" 10/17/2018 "'WELL SHUT IN UPON ARRIVAL"• (TROUBLESHOOT) STANDBY DUE TO HIGH WINDS WELL NOT FLOWING PROPERLY SO SHOOT FLUID LEVELS ON TBG AND IA A COUPLE TIMES (TBG= 7587' BELOW STA#5 / IA= 8294' (S/O GLV) "CONTINUE JOB ON 10-18-18 WSR" 1011812018 "'WELL SHUT IN ON ARRIVAL"" (TROUBLESHOOT) "PT PCE 2509-LOW/3,500#-HIGH" RATTLE ALL MANDRELS W/ 2.6" BELLGUIDE AND PULLING TOOLS, AND TAGGED XX LOCK @ 10269' SLM (10270' MD) (NO VLV RECOVERED) GET IMPRESSION OF TOP OF GLV LATCHES W/ 1.75" LIB IN STA'S # 4,5 & 6 PULL XX LOCK, FLOW THRU SUB AND GAUGES @ 10269 SLM (10270' MD) BATTERIES DISCONNTED @ 20:32 "CONTINUE JOB ON 10-19-18 WSR" 10/1912018 "'CONTINUE FROM 10-18-18 WSR, WELL SHUT IN ON ARRIVAL"' "PT PCE 250#-LOW/3,500#-HIGH" SET 31/2" XX LOCK, FLOW THRU SUB,TANDEM SPARTEK GAUGES IN X NIP @ 10269' SLM (10270' MD) RUN 3-1/2 CHECK SET TO XX LOCK @ 10269' SLM, GOOD SET PULL 1.5" LGLV'S FROM STA'S# 5 & 6 SET 1.5" DGLV (RK) IN STA'S# 6 & 5 LAY DOWN EQUIPMENT FOR NIGHT - NOTIFIED PAD OP TO BRING WELL ONLINE TO SEE IF IT WILL FLOW "CONTINUE JOB ON 10-20.18 10/20/2018 "'CONTINUE FROM 10-19-18 WSR, WELL SHUT IN ON ARRIVAL"' "PT PCE 250#-LOW/3,500#-HIGH" PULLED 1.5" SO GLV IN STA# 4 & SET LGLV (RK) STA# 4 @ 8298' SLM (8294' MD) MADE ONE ATTEMPT TO PULL STA# 1 W/ NO SUCCESS LAY DOWN EQUIPMENT FOR NIGHT - NOTIFIED PAD OP WELL TO REMAIN SHUT IN "CONTINUE JOB ON 10-22-18 WSR " 10/21/2018 "'CONTINUE FROM 10-20-18 WSR, WELL SHUT IN ON ARRIVAL— PT EQU I P 250 / 3500 PULL 1.5" DGLV IN STA# i @ 10197' SLM (10191' MD) SET 1.5" SO/ GLV, 24/64 PORTS, IN STA# 1 @ 10197' SLM (10191' MD) PULL 1.5" DGLV IN STA# 3 @ 9055' SLM (9088' MD) SET 1.5" LGLV, 16164 PORTS / 1773 TRO, IN STA# 3 @ 9055' SLM (9088' MD) PAD OP BRINGING WELL ONLINE UPON DEPARTURE "JOB COMPLETE" 10/23/2018 "'WELL SHUT IN UPON ARRIVAL"' PT LOW 250#/ high 3500# RIH WITH 3-1/2 GS TO 2400' SLM, STOP DUE TO THICK PARAFFIN WILL NEED TO HAVE A HOT DIESEL B&F TO CLEAR UP CALLED OFF DUE TO POSSIBLE RIG JOB ON 2-50 LATER TONIGHT EARLY MORNING "JOB POSTPONED " 10125/2018 PT PCE TO 250psi LOW - 3,OOOpsi HIGH F B&F TBG TO X-LOCK & FLOW THROUGH SUB PULL X-LOCK W/ FLOW THROUGH SUB & GAUGES FROM 10,266' SLM SHIFT XD SLIDING SLV UP TO CLOSE @ 10,351' SLM DRIFT FREELY TO TD 12 047' SLM W/ 29'x 2.29" DUMMY PERF GUNS, W/ 2.40" CENT ON TOP 8 2.68" CENT ON BTM 10/27/2018 PT PCE TO 250psi LOW - 3,OOOpsi HIGH DRIFT & TAG TO 12 051' SLM W/ 2.70" SWEDGE see fluid level 10,200' slm 10 212' and 10/29/20111 PT PCE 325 LOW 4000' HP PERFORATE 11905'- 11931' RKB W/ 6 SPF 60 DEG PHASED GUN 11 gm, CON NEX CHARGES. Hilcorp Alaska, LLC Duck Island Unit End MPI 2-66A 500292237401 Sperry Drilling Definitive Survey Report 02 October, 2018 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well 2-66 Project: Duck Island Unit TVD Reference: 2-66A Actual @ 40.O0usft Site: End MPI MD Reference: 2-66A Actual @ 40.00usft Well: 2-66 North Reference: True Wellbore: 2-66A Survey Calculation Method: Minimum Curvature Design: 2-66A Database: Sperry EDM - NORTH US + CANADA project Duck Island Unit, North Slope, UNITED STATES lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Asp Zone: Alaska Zone 03 Using geodetic scale factor Well 2-66, Previously known as 2-66/SD-12 2-66A Well Position +NIS 0.00 usft Northing: 5,982,293.29 usfl Latitude: 70° 21'8.101 N +E/ -W 0.00 usft Easting: 258,840.95 usfl Longitude: 147° 57'30.215 W Position Uncertainty 0.00 usft Wellhead Elevation: 13.30 usft Ground Level: 13.30 usft Wellbore 2-66A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1 (nn BGGM2018 8115/2018 17.48 81.05 57,461 Design 2-66A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,483.00 Vertical Section: Depth From (TVD) +NIS +EI -W Direction (usft) (usft) (usft) V) 26.70 0.00 0.00 246.17 Survey Program Date 10/2/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 33.00 7,483.00 2-66 Gyrodata CT Rate Gyro (2-66 P61) 2_Gyro-NS-CT_Csg+Cei H036Ga: Continuous in casing with centrollers 07/12/2018 7,503.00 7,583.14 2-66A MWD+InterpAzi+sag (2-66A) 2_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth +sag correction 09/11/2018 7,618.86 12,166.602-66A MWD+IFR2+MS+sag(2-66A) 2MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 09/21/2018 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.70 0.00 0.00 26.70 -13.30 0.00 0.00 5,982,293.29 258,640.95 0.00 0.00 UNDEFINED 33.00 0.29 216.98 33.00 -7.00 -0.01 -0.01 5,982,293.28 258,840.94 4.60 0.01 2_Gyro-NS-CT_Csg+Cent(1 58.00 0.37 201.95 58.00 18.00 -0.14 -0.08 5,982,293.15 258,840.87 0.47 0.13 2 Gyro-NS-CT_Csg+Cent (1 83.00 0.31 206.03 83.00 43.00 -0.27 -0.14 5,982,293.02 258,840.80 0.26 0.24 2_Gyro-NS-CT_Csg+Cent (1 108.00 0.35 205.10 108.00 68.00 -0.40 -0.20 5,982,292.89 258,840.74 0.16 0.35 2_Gyro-NS-CT_Csg+Cenl(1 133.00 0.33 210.46 133.00 93.00 -0.53 -0.27 5,982,292.76 258,840.66 0.15 0.46 2_Gyro-NS-CT_Csg+Cent (1 158.00 0.30 207.95 158.00 118.00 -0.65 -0.34 5,982,292.65 258,840.59 0.13 0.57 2_Gyro-NS-CT Csg+Cent (1 183.00 0.30 196.57 183.00 143.00 -0.78 -0.39 5,982,292.53 258,840.54 0.24 0.67 2_Gyro-NS-CT_Csg+Cent (1 208.00 0.41 184.56 208.00 168.00 -0.93 -0.41 5,982,292.38 258,840.51 0.53 0.75 2_Gyro-NS-CT_Csg+Cent (1 233.00 0.45 178.17 233.00 193.00 -1.11 -0.41 5,982,292.19 258,840.50 0.25 0.83 2_Gyro-NS-CT_Csg+Cent (1 258.00 0.48 191.65 258.00 218.00 -1.32 -0.43 5,982,291.99 258,840.47 0.45 0.93 2_Gyro-NS-CT_Csg+Cent (1 283.00 0.43 182.56 282.99 242.99 -1.51 -0.46 5,982,291.79 258,840.44 0.35 1.03 2_Gyro-NS-CT_Cs9+Cent (1 1022018 704:19PM Page 2 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well 2-66 Project: Duck Island Unit TVD Reference: 2-66A Actual @ 40.00usft Site: End MPI MD Reference: 2-66A Actual @ 40.00usft Well: 2-66 North Reference: True Wellbore: 2-66A Survey Calculation Method: Minimum Curvature Design: 2-66A Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100-) (ft) Survey Tool Name 308.00 0.56 181.44 307.99 267.99 -1.73 -0.47 5,982,291.58 258,840.43 0.52 1.12 2_Gyro-NS-CT_Csg+Cent (1 333.00 0.61 175.81 332.99 292.99 -1.98 -0.46 5,982,291.32 258,840.43 0.30 1.22 2_Gyro-NS-CT Csg+Cent (1 358.00 0.53 179.22 357.99 317.99 -2.23 -0.45 5,982,291.08 258,840.43 0.35 1.31 2_Gyro-NS-CT_Csg+Cent (1 383.00 0.57 174.69 382.99 342.99 -2.47 -0.43 5,982,290.84 258,840.44 0.24 1.40 2_Gyro-NS-CT_Csg+Cent (1 408.00 0.63 196.39 407.99 367.99 -2.73 -0.46 5,982,290.58 258,840.40 0.93 1.52 2_Gyro-NS-CT_Csg+Cent (1 433.00 0.96 220.94 432.99 392.99 -3.02 -0.64 5,982,290.30 258,840.22 1.87 1.80 2_Gyro-NS-CT_Csg+Cent (1 458.00 1.53 231.97 457.98 417.98 -3.38 -1.04 5,982,289.95 258,839.80 2.46 2.31 2_Gyro-NS-CT_Csg+Cent (1 483.00 2.17 237.81 482.97 442.97 -3.84 -1.70 5,982,289.51 258,839.13 2.67 3.11 2_Gyro-NS-CT_Cs9+Cent (1 508.00 2.70 240.24 507.94 467.94 -4.38 -2.61 5,982,288.99 258,838.20 2.16 4.16 2_Gyro-NS-CT_Csg+Cent(1 533.00 3.26 241.07 532.91 492.91 -5.02 -3.75 5,982,288.40 258,837.04 2.25 5.45 2_Gyro-NS-CT_Csg+Cent (1 558.00 3.44 241.21 557.87 517.87 -5.72 -5.03 5,982,287.73 258,835.74 0.72 6.91 2_Gyro-NS-CT_Csg+Cent (1 583.00 3.57 241.31 582.82 542.82 -6.46 -6.37 5,982,287.04 258,834.38 0.52 8.43 2 -Gym-NS-CT Csg+Cent (1 608.00 3.46 241.06 607.77 567.77 -7.20 -7.71 5,982,286.35 258,833.01 0.44 9.96 2_Gyro-NS-CT Csg+Cenl(1 633.00 3.28 240.68 632.73 592.73 -7.91 -8.99 5,982,285.67 258,831.71 0.73 11.42 2_Gyro-NS-CT_Csg+Cent (1 658.00 3.06 240.08 657.69 617.69 -8.59 -10.19 5,982,285.03 258,830.48 0.89 12.80 2_Gyro-NS-CT_Csg+Cent (1 683.00 3.03 239.81 682.66 642.66 -9.26 -11.34 5,982,284.40 258,829.31 0.13 14.12 2_Gym-NS-CT_Csg+Cent (1 708.00 3.04 240.25 707.62 667.62 -9.92 -12.49 5,982,283.78 258,828.15 0.10 15.43 2_Gyro-NS.CT_Csg+Cent (1 733.00 3.07 241.31 732.59 692.59 -10.57 -13.65 5,982,283.16 258,826.96 0.26 16.76 2_Gyro-NS-CT_Csg+Cent (1 758.00 3.17 243.70 757.55 717.55 -11.20 -14.86 5,982,282.58 258,825.74 0.66 18.12 2_Gyro-NS-CT Csg+Cent (1 783.00 3.34 246.24 782.51 742.51 -11.80 -16.15 5,982,282.02 258,824.43 0.89 19.54 2_Gyro-NS-CT_Csg+Cent(1 808.00 3.65 249.75 807.46 767.46 -12.37 -17.56 5,982,281.49 258,823.00 1.51 21.06 2_Gyro-NS-CT_Csg+Cent (t 833.00 3.78 250.94 832.41 792.41 -12.91 -19.09 5,982,281.00 258,821.46 0.60 22.68 2_Gyro-NS-CT_Csg+Cent (1 858.00 3.89 251.96 857.35 817.35 -13.44 -20.67 5,982,280.52 258,819.86 0.52 24.34 2_Gyro-NS-CT_Csg+Cent (1 883.00 3.94 251.82 882.30 842.30 -13.97 -22.29 5,982,280.04 258,818.22 0.20 26.04 2_Gyro-NS-CT_Csg+Cent (1 908.00 3.95 251.62 907.24 867.24 -14.51 -23.93 5,982,279.55 258,816.57 0.07 27.75 2 Gyro-NS-CT_Csg+Cent(1 933.00 3.97 251.48 932.18 892.18 -15.06 -25.56 5,982,279.06 258,814.92 0.09 29.47 2_Gyro-NS-CT_Csg+Cent (1 958.00 4.05 250.88 957.12 917.12 -15.62 -27.22 5,982,278.55 258,813.24 0.36 31.21 2_Gyro-NS-CT_Csg+Cent (1 983.00 4.06 249.73 982.05 942.05 -16.22 -28.88 5,982,278.01 258,811.56 0.33 32.97 2 -Gym -NS -CT Csg+Cent (1 1,008.00 4.08 247.79 1,006.99 966.99 -16.86 -30.54 5,982,277.42 258,809.89 0.56 34.75 2_Gyro-NS-CT_Csg+Cent(1 1,033.00 4.13 246.43 1,031.93 991.93 -17.56 -32.19 5,982,276.78 258,808.22 0.44 36.54 2_Gyro-NS-CT_Csg+Cenl(1 1,058.00 4.20 244.93 1,056.86 1,016.86 -18.31 -33.84 5,982,276.08 258,806.54 0.52 38.35 2_Gyro-NS-CT_Csg+Cent (1 1,083.00 4.22 243.89 1,081.79 1,041.79 -19.10 -35.49 5,982,275.34 258,804.86 0.32 40.19 2_Gyro-NS-CT_Csg+Cent(1 1,108.00 4.28 242.64 1,106.72 1,066.72 .19.93 -37.15 5,982,274.56 258,803.18 0.44 42.04 2_Gyro-NS-CT_Csg+Cent(1 1,133.00 4.35 241.67 1,131.65 1,091.65 -20.81 -38.81 5,982,273.74 258,801.49 0.40 43.91 2_Gym-N8-CT_C8g+Cent(1 1,158.00 4.41 240.97 1,156.58 1,116.58 -21.73 -40.49 5,982,272.88 258,799.79 0.32 45.81 2_Gyro-NS-CT_Cs9+Cent(1 1,183.00 4.48 240.89 1,181.50 1,141.50 -22.67 42.18 5,982,271.99 258,798.06 0.28 47.74 2_Gyro-NS-CT_Csg+Cenl(1 1,208.00 4.50 240.57 1,206.43 1,166.43 .23.63 -43.89 5,982,271.09 258,796.33 0.13 49.69 2_Gyro-NS-CT_Csg+Cent(1 1,233.00 4.66 240.70 1,231.35 1,191.35 -24.61 -45.63 5,982,270.17 258,794.56 0.64 51.68 2_Gym-1,15-CT_Csg+Cent it 1,258.00 4.67 240.15 1,256.27 1,216.27 -25.61 -47.40 5,982,269.22 258,792.76 0.18 53.70 2_Gyro-NS-CT_Csg+Cent(1 1,283.00 4.96 240.51 1,281.18 1,241.18 -26.65 -49.22 5,982,268.24 258,790.90 1.17 55.79 2_Gyro-NS-CT_Csg+Cent(1 10!2/2018 7:04:19PM Page 3 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Duck Island Unit End MPI 2-66 2-66A 2-66A Local Co-ordinate Reference: Well 2-66 TVD Reference: 2-66A Actual @ 40.00usft MD Reference: 2-66A Actual @ 40.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E1 -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,308.00 5.35 241.27 1,306.08 1,266.08 -27.74 -51.18 5,982,267.21 258,788.90 1.58 58.03 2_Gym-NS-CT_Csg+Cenl(1 1,333.00 5.78 241.62 1,330.96 1,290.96 -28.90 -53.31 5,982,266.12 258,786.74 1.73 60.44 2_Gyro-NS-CT_Csg+Cent (1 1,358.00 6.28 242.82 1,355.82 1,315.82 -30.12 -55.64 5,982,264.98 258,784.38 2.06 63.06 2_Gyro-NS-CT_Csg+Cent(1 1,383.00 6.59 243.46 1,380.66 1,340.66 -31.39 -58.14 5,962,263.79 258,781.84 1.27 65.86 2_Gyro-NS-CT_Csg+Cent (1 1,408.00 6.87 244.06 1,405.49 1,365.49 -32.68 -60.76 5,982,262.58 258,779.17 1.15 68.79 20yro-NS-CT_Csg+Cent(1 1,433.00 7.32 244.26 1,430.30 1,390.30 -34.03 -63.54 5,982,261.33 258,776.35 1.80 71.87 2_Gyro-NS-CT_Csg+Cent(1 1,458.00 7.90 244.88 1,455.08 1,415.08 -35.45 -66.53 5,982,260.00 258,773.31 2.34 75.18 2_Gyro-NS-CT_Csg+Cent (1 1,483.00 8.85 245.01 1,479.81 1,439.81 -36.99 -69.83 5,982,258.57 258,769.97 3.80 78.82 2 Gyro -NS -CT Csg+Cent (1 1,508.00 9.81 244.59 1,504.48 1,464.48 -38.72 -73.50 5,982,256.96 258,766.25 3.85 82.88 2_Gyro-NS-CT_Csg+Cent It 1,533.00 10.58 243.56 1,529.09 1,489.09 -40.65 -77.48 5,982,255.15 258,762.21 3.17 87.30 2_Gyrc-NS-CT_Csg+Cent(1 1,558.00 11.53 242.87 1,553.62 1,513.62 42.81 -81.76 5,982,253.13 258,757.86 3.84 92.08 2_Gyro-NS-CT_Csg+Cent(1 1,583.00 11.83 242.01 1,578.10 1,538.10 45.16 -86.24 5,982,250.93 258,753.30 1.39 97.13 2_Gyro-NS-CT_Csg+Cent(1 1,608.00 12.04 241.22 1,602.56 1,562.56 37.61 -90.79 5,982,248.62 258,748.68 1.06 102.29 2_Gyn-NS-CT_Csg+Cent It 1,633.00 12.46 239.81 1,626.99 1,586.99 -50.23 -95.41 5,982,246.16 258,743.98 2.06 107.57 2_Gyro-NS-CT_Csg+Cent (1 1,658.00 12.86 238.87 1,651.39 1,611.39 -53.02 -100.12 5,982,243.52 258,739.18 1.80 113.01 2_Gyro-NS-CT_Csg+Cent(1 1,683.00 13.41 237.86 1,675.73 1,635.73 -56.00 -104.96 5,982,240.70 258,734.25 2.38 118.63 2_Gyro-NS-CT_Csg+Cent(1 1,708.00 14.40 236.56 1,700.00 1,660.00 -59.26 -110.00 5,982,237.61 258,729.10 4.15 124.57 2_Gyro-NS-CT_Csg+Cent (1 1,733.00 15.18 235.40 1,724.17 1,684.17 -62.83 -115.29 5,982,234.21 258,723.70 3.34 130.85 2_Gym-NS-CT_Csg+Cent (1 1,758.00 15.94 234.23 1,748.25 1,708.25 -66.69 -120.77 5,982,230.52 258,718.10 3.29 137.42 2 Gyro-NS-CT_Csg+Cent(1 1,783.00 16.20 234.06 1,772.28 1,732.28 -70.75 -126.38 5,982,226.65 258,712.36 1.06 144.19 2_Gyro-NS-CT_Csg+Cent(1 1,808.00 16.63 233.95 1,796.26 1,756.26 -74.90 .132.10 5,982,222.68 258,706.51 1.72 151.10 2_Gyro-NS-CT_Csg+Cent (1 1,833.00 17.77 234.11 1,820.14 1,780.14 -79.24 -138.08 5,982,218.54 258,700.39 4.56 158.32 2_Gyro-NS-CT_Csg+Cent (1 1,858.00 18.38 234.09 1,843.91 1,803.91 -83.79 -144.36 5,982,214.19 258,693.97 2.44 165.91 2_Gyro-NS-CT_Csg+Cent (1 1,883.00 18.95 233.91 1,867.59 1,827.59 -88.49 -150.84 5,982,209.70 258,687.35 2.29 173.73 2_Gyro-NS-CT_Csg+Cent(1 1,908.00 19.92 233.82 1,891.17 1,851.17 -93.40 .157.55 5,982,205.02 258,680.48 3.88 181.86 2_Gyro-NS-CT_Cs9+Cent (1 1,933.00 20.67 233.70 1,914.61 1,874.61 -98.52 -164.55 5,982,200.12 258,673.32 3.00 190.33 2_Gyro-NS-CT_Csg+Cent (1 1,958.00 21.47 233.61 1,937.94 1,897.94 -103.85 -171.79 5,982,195.03 258,665.91 3.20 199.10 2_Gyro-NS-CT_Csg+Cent(1 1,983.00 22.34 233.28 1,961.14 1,921.14 -109.41 -179.28 5,982,189.72 258,658.25 3.51 208.20 2_Gyro-NS-CT_Csg+Cenl(1 2,008.00 23.13 232.96 1,984.19 1,944.19 -115.20 -187.01 5,982,184.17 258,650.34 3.20 217.61 2_Gyro-NS-CT_Csg+Cent(1 2,033.00 24.36 232.55 2,007.08 1,967.08 -121.30 -195.02 5,982,178.34 258,642.13 4.96 227.40 2_Gyro-NS-CT_Csg+Cent(1 2,058.00 25.16 232.69 2,029.78 1,989.78 -127.65 -203.34 5,982,172.25 258,633.61 3.21 237.58 2_Gyro-NS-CT_Csg+Cent(1 2,083.00 25.94 232.76 2,052.33 2,012.33 -134.18 -211.92 5,982,166.00 258,624.83 3.12 248.07 2_Gyr0-NS-CT_Csg+Cent(1 2,108.00 27.24 233.00 2,074.69 2,034.69 -140.94 -220.84 5,982,159.54 258,615.69 5.22 258.96 2_Gyr0-NS.CT_Csg+Cent(1 2,133.00 27.93 233.14 2,096.85 2,056.85 -147.89 -230.10 5,982,152.89 258,606.22 2.77 270.23 2_Gyro-NS.CT_Csg+Cent(1 2,158.00 28.58 233.24 2,118.87 2,078.87 -154.98 -239.57 5,982,146.10 258,596.52 2.61 281.77 2_Gyro-NS-CT_Csg+Cent(1 2,183.00 29.17 233.33 2,140.76 2,100.76 -162.20 -249.25 5,982,139.20 258,586.62 2.37 293.53 2_Gyro-NS-CT_Csg+Cent(1 2,208.00 29.49 233.43 2,162.56 2,122.56 -169.50 -259.08 5,982,132.22 258,576.56 1.29 305.48 2_Gyro-NS-CT_Csg+Cent(1 2,233.00 29.81 233.57 2,184.28 2,144.28 -176.86 -269.02 5,982,125.19 258,566.39 1.31 317.54 2_Gyro-NS-CT_Csg+Cent(1 2,258.00 30.01 233.69 2,205.95 2,165.95 -184.25 -279.06 5,982,118.12 258,556.12 0.84 329.71 2_Gyro-NS-CT_Csg+Cent(1 2,283.00 30.22 233.77 2,227.58 2,187.58 -191.67 -289.17 5,982,111.03 258,545.77 0.86 341.96 2_Gyro-NS-CT_Csg+Cent(1 1022018 7:04:19PM Page 4 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well 2-66 Project: Duck Island Unit TVD Reference: 2-66A Actual @ 40.00usft Site: End MPI MD Reference: 2-66A Actual @ 40.00usft Well: 2-66 North Reference: True Wellbore: 2-66A Survey Calculation Method: Minimum Curvature Design: 2-66A Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 2,308.00 30.26 234.02 2,249.18 2,209.18 -199.09 -299.34 5,982,103.94 258,535.36 0.53 354.26 2_Gyro-NS-CT_Csg+Cent(1 2,333.00 30.13 234.25 2,270.78 2,230.78 -206.46 -309.53 5,982,096.91 258,524.94 0.70 366.56 2_Gyro-NS-CT_Csg+Cent (1 2,358.00 30.01 234.41 2,292.42 2,252.42 -213.76 -319.71 5,982,089.93 258,514.54 0.58 378.82 2 Gyro -NS -CT Csg+Cent(1 2,383.00 29.82 234.73 2,314.09 2,274.09 -220.99 -329.87 5,982,083.04 258,504.15 0.99 391.03 2_Gyro-NS-CT_Csg+Cent(1 2,408.00 29.87 234.85 2,335.77 2,295.77 -228.17 -340.03 5,982,076.19 258,493.76 0.31 403.23 2_Gyro-NS-CT_Csg+Cent(1 2,433.00 29.91 234.99 2,357.45 2,317.45 -235.33 -350.23 5,982,069.37 258,483.34 0.32 415.45 2_Gyro-NS-CT_Csg+Cent (1 2,458.00 30.14 234.91 2,379.09 2,339.09 -242.51 -360.47 5,982,062.52 258,472.87 0.93 427.72 2_Gyro-NS-CT_Csg+Cent (1 2,483.00 30.46 234.75 2,400.68 2,360.68 -249.77 -370.78 5,982,055.59 258,462.34 1.32 440.09 2 Gym-NS-CT_Csg+Cent (1 2,508.00 30.95 234.53 2,422.17 2,382.17 -257.16 -381.19 5,982,048.54 258,451.69 2.01 452.59 2_Gyro-NS-CT_Csg+Cent (1 2,533.00 31.16 234.65 2,443.59 2,403.59 -264.63 -391.70 5,982,041.41 258,440.95 0.88 465.23 2_Gyro-NS-CT_Csg+Cent (1 2,558.00 31.16 234.78 2,464.98 2,424.98 -272.11 402.26 5,982,034.28 258,430.15 0.27 477.91 2_Gyro-NS-CT_Csg+Cent (1 2,583.00 30.91 235.07 2,486.40 2,446.40 -279.51 -412.81 5,982,027.22 258,419.37 1.17 490.55 2_Gyro-NS-CT_Csg+Cent (1 2,608.00 30.88 235.14 2,507.86 2,467.86 -286.86 -423.34 5,982,020.22 258,408.61 0.19 503.15 2 Gyrc-NS-CT Csg+Cent (1 2,633.00 30.93 235.08 2,529.31 2,489.31 -294.20 -433.87 5,982,013.21 258,397.85 0.23 515.75 2_Gyro-NS-CT_Csg+Cent(1 2,658.00 30.96 234.81 2,550.75 2,510.75 -301.59 444.39 5,982,006.17 258,387.09 0.57 528.36 2_Gyro-NS-CT_Csg+Cent (1 2,683.00 31.07 234.68 2,572.18 2,532.18 -309.02 -454.91 5,981,999.08 258,376.34 0.52 540.98 2_Gyro-NS-CT_Csg+Cent(1 2,708.00 31.01 234.61 2,593.60 2,553.60 -316.48 465.43 5,981,991.96 258,365.59 0.28 553.61 2_Gyro-NS-CT_Csg+Cent(1 2,733.00 30.79 234.74 2,615.05 2,575.05 -323.90 475.90 5,981,984.88 258,354.89 0.92 566.19 2_Gyro-NS-CT_Csg+Cent (1 2,758.00 30.65 234.81 2,636.54 2,596.54 -331.27 486.33 5,981,977.86 258,344.22 0.58 578.71 2_Gyro-NS-CT_Csg+Cent (1 2,783.00 30.52 234.89 2,658.06 2,618.06 -338.59 496.73 5,981,970.87 258,333.59 0.54 591.19 2_Gyro-NS-CT_Csg+Cent(1 2,808.00 30.47 234.99 2,679.60 2,639.60 -345.88 -507.12 5,981,963.92 258,322.98 0.28 603.63 2_Gyro-NS-CT_Csg+Cent (1 2,833.00 30.57 235.09 2,701.14 2,661.14 -353.16 -517.52 5,981,956.99 258,312.35 0.45 616.09 2_Gyro-NS-CT_Csg+Cent (1 2,858.00 30.43 235.60 2,722.68 2,682.68 -360.37 -527.96 5,981,950.11 258,301.68 1.18 628.55 2_Gyro-NS-CT_Csg+Cent (1 2,883.00 30.60 235.35 2,744.22 2,704.22 -367.57 -538.42 5,981,943.26 258,291.00 0.85 641.02 2_Gyro-NS-CT_Csg+Cent(1 2,908.00 30.87 234.77 2,765.71 2,725.71 -374.88 -548.89 5,981,936.28 258,280.29 1.60 653.56 2_Gyro-NS-CT_Csg+Cent (1 2,933.00 30.67 235.05 2,787.19 2,747.19 -382.24 -559.36 5,981,929.27 258,269.60 0.98 666.10 2 Gyro -NS -CT Csg+Cent (1 2,958.00 30.61 234.75 2,808.70 2,768.70 -389.56 -569.78 5,981,922.28 258,258.94 0.66 678.60 2_Gyro-NS-CT_Csg+Cent(1 2,983.00 30.67 234.33 2,830.21 2,790.21 -396.95 -580.16 5,981,915.23 258,248.33 0.89 691.08 2_Gym-NS-CT_Csg+Cent (1 3,008.00 30.77 234.47 2,851.70 2,811.70 -404.39 -590.54 5,981,908.13 258,237.72 0.49 703.58 2_Gyro-NS-CT_Csg+Cent (1 3,033.00 30.68 234.40 2,873.19 2,833.19 411.82 -600.93 5,981,901.04 258,227.09 0.39 716.09 2_Gyro-NS-CT_Csg+Cent (1 3,058.00 30.86 234.07 2,894.67 2,854.67 -419.29 -611.31 5,981,893.90 258,216.48 0.99 728.60 2_Gyro-NS-CT_Csg+Cent (1 3,083.00 31.68 233.37 2,916.04 2,876.04 -426.97 -621.77 5,981,886.57 258,205.78 3.59 741.27 2_Gyro-NS-CT_Csg+Cent (1 3,108.00 32.55 233.49 2,937.21 2,897.21 434.89 -632.45 5,981,879.00 258,194.86 3.49 754.24 2_Gyro-NS-CT_Csg+Cent(I 3,133.00 33.01 232.79 2,958.23 2,918.23 443.01 -643.28 5,981,871.23 258,183.77 2.38 767.42 2_Gyro-NS-CT_Csg+Cent(1 3,158.00 33.48 232.44 2,979.14 2,939.14 451.33 -664.17 5,981,863.26 258,172.62 2.03 780.75 2_Gyro-NS-CT_Cs9+Cenl(1 3,183.00 34.13 232.10 2,999.91 2,959.91 -459.84 -665.17 5,981,855.11 258,161.35 2.71 794.25 2_Gyro-NS-CT_Csg+Cent(1 3,208.00 33.68 232.87 3,020.66 2,980.66 468.34 -676.23 5,981,846.98 258,150.02 2.49 807.80 2 Gyro -NS -CT Gsg+Cent(1 3,233.00 33.48 232.98 3,041.49 3,001.49 476.67 -687.26 5,981,839.00 258,138.73 0.84 821.26 2_Gyro-NS-CT_Csg+Cent(1 3,258.00 33.77 232.70 3,062.31 3,022.31 -485.03 -698.29 5,981,831.00 258,127.43 1.32 834.73 2_Gyro-NS-CT_Csg+Cenl(1 3,283.00 34.26 232.44 3,083.03 3,043.03 -493.53 -709.40 5,981,822.86 258,116.06 2.04 848.32 2 Gyro-NS-CT_Csg+Cent(1 10122018 7.04:19PM Page 5 COMPASS 5000.1 Build 81E Company: Hilcorp Alaska, LLC Project: Duck Island Unit Site: End MPI Well: 2-66 Wellbore: 2-66A Design: 2-66A Survey MD Inc (usft) (I 3,308.00 34.46 3,333.00 34.35 3,358.00 34.15 3,383.00 34.36 3,408.00 34.33 3,433.00 34.59 3,458.00 35.17 3,483.00 35.59 3,508.00 36.48 3,533.00 36.83 3,558.00 37.60 3,583.00 38.16 3,608.00 38.58 3,633.00 39.23 3,658.00 39.64 3,683.00 39.79 3,708.00 40.10 3,733.00 40.33 3,758.00 40.70 3,783.00 41.66 3,808.00 42.14 3,833.00 42.75 3,858.00 43.92 3,883.00 44.82 3,908.00 45.26 3,933.00 46.19 3,958.00 47.34 3,983.00 47.80 4,008.00 48.16 4,033.00 48.12 4,058.00 48.20 4,083.00 47.89 4,108.00 47.76 4,133.00 47.65 4,158.00 47.46 4,183.00 47.38 4,208.00 47.51 4,233.00 47.59 4,258.00 47.83 4,283.00 48.10 Azi 232.51 232.96 232.85 232.90 232.73 233.18 233.06 233.39 233.67 233.75 233.16 233.45 234.11 233.37 233.43 233.37 233.20 233.16 232.87 232.43 232.10 231.46 231.05 230.68 230.24 229.74 229.39 229.44 229.47 229.81 230.06 230.37 230.52 230.84 231.08 231.43 231.81 232.16 232.26 232.37 Halliburton Definitive Survey Report TVD TVDSS +NI -S (usft) (usft) (usft) 3,103.67 3,063.67 -502.13 3,124.29 3,084.29 -510.68 3,144.96 3,104.96 -519.17 3,165.62 3,125.62 -527.66 3,186.26 3,146.26 -536.19 3,206.88 3,166.88 -544.71 3,227.38 3,187.38 -553.29 3,247.77 3,207.77 -561.95 3,267.98 3,288.04 3,307.95 3,327.68 3,347.28 3,366.74 3,386.04 3,405.28 3,424.44 3,443.53 3,462.54 3,481.35 3,499.96 3,518.41 3,536.59 3,554.46 3,572.13 3,589.58 3,606.71 3,623.57 3,640.31 3,656.99 3,673.67 3,690.38 3,707.17 3,723.99 3,740.86 3,757.78 3,774.69 3,791.56 3,808.38 3,825.12 3,227.98 3,248.04 3,267.95 3,287.68 3,307.28 3,326.74 3,346.04 3,365.28 3,384.44 3,403.53 3,422.54 3,441.35 3,459.96 3,478.41 3,496.59 3,514.46 3,532.13 3,549.58 3,566.71 3,583.57 3,600.31 3,616.99 3,633.67 3,650.38 3,667.17 3,683.99 3,700.86 3,717.78 3,734.69 3,751.56 3,768.38 3,785.12 -570.69 -579.53 -588.53 -597.70 -606.87 -616.16 -625.63 -635.15 -644.75 -654.42 -664.19 -674.18 -684.40 -694.84 -705.57 -716.61 -727.87 -739.38 -751.19 -763.20 -775.27 -787.33 -799.32 -811.21 -823.01 -834.73 -846.35 -857.87 -869.30 -880.66 -892.00 -903.35 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +EI -W Northing (usft) (ft) -720.59 5,981,814.63 -731.83 5,981,806.44 -743.05 5,981,798.32 -754.27 5,981,790.20 -765.51 5,981,782.04 -776.80 5,981,773.89 -788.24 5,981,765.68 -799.83 5,981,757.39 -811.66 5,981,749.03 -823.69 5,981,740.59 -835.83 5,981,731.98 -848.14 5,981,723.21 -860.66 5,981,714.45 -873.32 5,981,705.58 -886.07 5,981,696.53 -898.89 5,981,687.42 -911.76 5,981,678.24 -924.68 5,981,668.99 -937.66 5,981,659.64 -950.74 5,981,650.08 -963.94 5,981,640.30 -977.20 5,981,630.29 -990.58 5,981,619.99 -1,004.14 5,981,609.40 -1,017.78 5,981,598.58 -1,031.49 5,981,587.52 -1,045.35 5,981,576.16 -1,059.37 5,981,564.61 -1,073.48 5,981,553.00 -1,087.67 5,981,541.40 -1,101.92 5,981,529.88 -1,116.21 5,981,518.45 -1,130.49 5,981,507.12 -1,144.80 5,981,495.87 -1,159.13 5,981,484.72 -1,173.49 5,981,473.66 -1,187.92 5,981,462.70 -1,202.46 5,981,451.81 -1,217.07 5,981,440.96 -1,231.76 5,981,430.09 Well 2-66 2-66A Actual @ 40.O0usft 2-66A Actual @ 40.00usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Easting DLS (ft) (°1100') 258,104.60 0.82 258,093.09 1.11 258,081.60 0.84 258,070.11 0.85 258,058.61 0.40 258,047.05 1 A 258,035.34 2.34 258,023.47 1.85 258,011.37 3.62 257,999.07 1.41 257,986.64 3.39 257,974.04 2.35 257,961.23 2.35 257,948.28 3.20 257,935.23 1.65 257,922.11 0.62 257,908.94 1.31 257,895.71 0.93 257,882.43 1.66 257,869.04 4.01 257,855.51 2.11 257,841.93 2.99 257,828.21 4.81 257,814.30 3.75 257,800.30 2.16 257,786.23 3.99 257,772.00 4.71 257,757.60 1.85 257,743.11 1.44 257,728.54 1.03 257,713.91 0.81 257,699.25 1.55 257,684.59 0.68 257,669.92 1.04 257,655.22 1.04 257,640.50 1.08 257,625.70 1.23 257,610.81 1.08 257,595.84 1.00 257,580.79 1.13 Vertical Section (ft) Survey Tool Name 862.03 2-Gyro-NS-CTCsg+Cent (1 875.77 2_Gyro-NS-CT_Csg+Cent(1 889.46 2_Gym-NS-CT Csg+Cenl(1 903.16 2_Gyro-NS-CT_Cs9+Cent (1 916.88 2_Gym-NS-CT_Csg+Cent(1 930.65 2_Gyro-NS-CT_Csg+Cent(1 944.58 2_Gyro-NS-CT_Csg+Cent(1 958.69 2_Gym-NS-CT_Csg+Cent(1 973.04 2_Gyro-NS-CT_Csg+Cent (1 987.61 2_Gyr NS -CT _Csg+Cent(1 1,002.36 2_Gyro-NS-CT_Csg+Cent(1 1,017.32 2_Gyro-NS-CT Csg+Cent (1 1,032.48 2_Gyro-NS-CT Csg+Cent (1 1,047.81 2_Gym-NS-CT_Csg+Cent (1 1,063.30 2_Gyro-NS-CT_Csg+Ceni(1 1,078.88 2_Gym-NS-CT_Csg+Cent (1 1,094.53 2_Gyro-NS-CT_Csg+Cent(1 1,110.25 2_Gyro-NS-CT_Csg+Cenl(1 1,126.07 2_Gym-NS-CT Csg+Cent(1 1,142.07 2_Gyro-NS-CT_Csg+Cent(1 1,158.28 2_Gyro-NS-CT_Csg+Cent(1 1,174.62 2_Gym-NS-CT_Csg+Cent (1 1,191.20 2_Gyro-NS-CT_Csg+Cent(1 1,208.06 2_Gyra-NS-CT_Csg+Cent (1 1,225.09 2_Gyro-NS-CT_Csg+Cent (1 1,242.28 2_Gyro-NS-CT Csg+Cent (1 1,259.73 2_Gyro-NS-CT_Csg+Cent (1 1,277.40 2_Gym-NS-CT_Csg+Cent (1 1,295.19 2_Gyro-NS-CT_Csg+Cent (1 1,313.04 2 Gyro-NS-CT_Csg+Cent(1 1,330.92 2_Gyro-NS-CT_Cs9+Cent(1 1,348.80 2_Gyro-NS-CT_Csg+Cent(1 1,366.63 2_Gyro-NS-CT_Csg+Cent (1 1,384.45 2_Gyro-NS-CT_Csg+Cent(1 1,402.26 2_Gyro-NS-CT_Csg+Cent(1 1,420.04 2_Gyro-NS-CT_Cs9+Cent(1 1,437.87 2_Gyro-NS-CT_Csg+Cent (1 1,455.75 2_Gyro-NS-CT_Csg+Cent (1 1,473.70 2_Gyro-NS-CT_Csg+Cent (1 1,491.73 2_Gyro-NS-CT_Csg+Cent(1 10/22018 7:04:19PM Page 6 COMPASS 5000.1 Build 81 E Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Duck Island Unit End MPI 2-66 2-66A 2-66A Local Co-ordinate Reference: Well 2-66 TVD Reference: 2-66A Actual @ 40.00usft MD Reference: 2-66A Actual @ 40.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 4,308.00 48.71 232.42 3,841.72 3,801.72 -914.76 -1,246.58 5,981,419.16 257,565.62 2.44 1,509.89 2_Gyro-NS-CT_Csg+Cent (1 4,333.00 49.65 232.27 3,858.06 3,818.06 -926.31 -1,261.55 5,981,408.09 257,550.28 3.79 1,528.26 2_Gyro-NS-CT_Csg+Cent(1 4,358.00 50.16 232.31 3,874.16 3,834.16 -938.01 -1,276.68 5,981,396.89 257,534.78 2.04 1,546.82 2_Gyro-NS-CT_Csg+Cent(1 4,383.00 50.79 232.42 3,890.07 3,850.07 -949.79 -1,291.96 5,981,385.61 257,519.14 2.54 1,565.55 2_Gyro-NS-CT Csg+Cent (1 4,408.00 51.48 232.21 3,905.76 3,865.76 -961.69 -1,307.36 5,981,374.21 257,503.36 2.84 1,584.45 2_Gyro-NS-CT_Csg+Cent(1 4,433.00 51.74 232.26 3,921.28 3,881.28 -973.69 -1,322.85 5,981,362.72 257,487.49 1.05 1,603.47 2_Gyro-NS-CT_Csg+Cent(1 4,458.00 51.83 232.27 3,936.75 3,896.75 -985.71 -1,338.38 5,981,351.20 257,471.58 0.36 1,622.54 2_Gyro-NS-CT_Csg+Cent (1 4,483.00 51.81 232.34 3,952.20 3,912.20 -997.72 -1,353.93 5,981,339.69 257,455.65 0.23 1,641.61 2_Gyro-NS-CT_Csg+Cent (1 4,508.00 51.77 232.35 3,967.67 3,927.67 -1,009.73 -1,369.49 5,981,328.20 257,439.72 0.16 1,660.69 2_Gyro.NS-CT_Csg+Cent(1 4,533.00 51.84 232.44 3,983.12 3,943.12 -1,021.71 -1,385.05 5,981,316.72 257,423.78 0.40 1,679.77 2_Gyro-NS-CT_Csg+Cenl(1 4,558.00 51.81 232.40 3,998.58 3,958.58 -1,033.70 -1,400.63 5,981,305.24 257,407.83 0.17 1,698.86 2_Gyro-NS-CT_Csg+Cent(1 4,583.00 51.62 232.48 4,014.07 3,974.07 -1,045.66 -1,416.18 5,981,293.79 257,391.89 0.80 1,717.92 2_Gyro-NSCT_Csg+Cent(1 4,608.00 51.70 232.62 4,029.57 3,989.57 -1,057.59 -1,431.75 5,981,282.37 257,375.95 0.54 1,736.98 2 Gyro.NSCT_Csg+Cent(1 4,633.00 51.13 233.07 4,045.17 4,005.17 -1,069.39 -1,447.33 5,981,271.07 257,360.00 2.68 1,756.00 2_Gyro-NS.CT_Csg+Cent(1 4,658.00 50.80 232.83 4,060.91 4,020.91 -1,081.09 -1,462.82 5,981,259.88 257,344.14 1.52 1,774.90 2_Gyro-NS-CT_Csg+Cent(1 4,683.00 50.50 232.24 4,076.76 4,036.76 -1,092.85 .1,478.17 5,981,248.62 257,328.42 2.18 1,793.69 2_Gyro-NSCT_Csg+Cent(1 4,708.00 50.23 231.96 4,092.71 4,052.71 -1,104.68 -1,493.36 5,981,237.29 257,312.86 1.38 1,812.36 2_Gyro-NS-CT_Csg+Cent(1 4,733.00 50.70 232.00 4,108.62 4,068.62 -1,116.55 -1,508.55 5,981,225.91 257,297.30 1.88 1,831.06 2_Gyro-NS-CT_Csg+Cent(1 4,758.00 50.64 231.86 4,124.47 4,084.47 -1,128.48 -1,523.77 5,981,214.48 257,281.70 0.50 1,849.80 2_Gyro-NS-CT_Csg+Cent(1 4,783.00 50.74 231.71 4,140.31 4,100.31 -1,140.44 -1,538.97 5,981,203.01 257,266.12 0.61 1,868.54 2_Gyro.NS-CT_Csg+Cent(1 4,808.00 50.97 231.64 4,156.09 4,116.09 -1,152.46 -1,554.18 5,981,191.48 257,250.53 0.95 1,887.31 2_Gyre-NS-CT_Csg+Cent(1 4,833.00 51.27 231.47 4,171.78 4,131.78 -1,164.56 -1,569.42 5,981,179.88 257,234.91 1.31 1,906.14 2_Gyro-NS-CT_Csg+Cenl(1 4,858.00 51.15 231.46 4,187.44 4,147.44 -1,176.70 -1,584.67 5,981,168.24 257,219.28 0.48 1,924.99 2_Gyro-NS-CT_Csg+Cent(1 4,883.00 50.50 231.60 4,203.23 4,163.23 -1,188.76 -1,599.84 5,981,156.68 257,203.73 2.64 1,943.74 2_Gyro.NS-CT_Csg+Cent(1 4,908.00 50.22 231.66 4,219.18 4,179.18 -1,200.71 -1,614.93 5,981,145.22 257,188.26 1.14 1,962.37 2_Gym-NS-CT_Cs9+Cenl(1 4,933.00 50.22 231.75 4,235.18 4,195.18 -1,212.62 -1,630.01 5,981,133.80 257,172.81 0.28 1,980.98 2 Gyro-NS-CT_Csg+Cent(1 4,958.00 50.24 231.74 4,251.17 4,211.17 -1,224.52 -1,645.10 5,981,122.40 257,157.34 0.09 1,999.59 2_Gyro-NS-CT_Csg+Cent(1 4,983.00 50.14 231.81 4,267.18 4,227.18 -1,236.40 -1,660.19 5,981,111.01 257,141.88 0.45 2,018.19 2_Gyro-NS-CT_Csg+Cent(1 5,008.00 50.34 231.90 4,283.17 4,243.17 -1,248.27 -1,675.30 5,981,099.63 257,126.40 0.85 2,036.81 2_Gym-NS-CT_Csg+Cenl(I 5,033.00 50.35 231.96 4,299.12 4,259.12 -1,260.14 -1,690.46 5,981,088.26 257,110.87 0.19 2,055.47 2_Gyr0-NS-CT_Csg+Cent(1 5,058.00 50.19 232.14 4,315.10 4,275.10 -1,271.96 -1,705.62 5,981,076.93 257,095.34 0.85 2,074.11 2_Gyro-NS-CT_Csg+Cent(1 5,083.00 49.94 232.21 4,331.15 4,291.15 -1,283.72 -1,720.76 5,981,065.67 257,079.82 1.02 2,092.71 2_Gyro-NS-CT_Csg+Cent (1 5,108.00 49.40 232.32 4,347.33 4,307.33 -1,295.38 -1,735.83 5,981,054.49 257,064.39 2.19 2,111.21 2_Gym-NS-CT_Csg+Cent(1 5,133.00 49.55 232.30 4,363.57 4,323.57 -1,307.00 -1,750.87 5,981,043.37 257,048.98 0.60 2,129.66 2_Gym-NS-CT_Csg+Cent(1 5,158.00 49.88 232.44 4,379.74 4,339.74 -1,318.64 -1,765.97 5,981,032.21 257,033.51 1.39 2,148.18 2_Gyro-NS-CT Csg+Cent(1 5,183.00 50.05 232.37 4,395.82 4,355.82 -1,330.32 -1,781.14 5,981,021.03 257,017.98 0.71 2,166.77 2_Gyro-NS-CT_Csg+Cent(1 5,208.00 50.42 232.45 4,411.81 4,371.81 -1,342.04 -1,796.37 5,981,009.81 257,002.38 1.50 2,185.44 2_Gyro-NS-CT_Csg+Cent(I 5,233.00 50.54 232.44 4,427.72 4,387.72 -1,353.80 -1,811.65 5,980,998.55 256,986.72 0.48 2,204.17 2_Gyro-NS-CT_Csg+Cent (1 5,258.00 50.42 232.56 4,443.63 4,403.63 -1,365.54 -1,826.95 5,980,987.31 256,971.05 0.61 2,222.91 2_Gyro-NS-CT_Csg+Cent(1 5,283.00 49.66 232.79 4,459.68 4,419.68 -1,377.16 -1,842.19 5,980,976.19 256,955.45 3.12 2,241.55 2_Gyro-NS-CT_Csg+Cent(1 1022018 7.,04:19PM Page 7 COMPASS 5000.1 Build SIE Company: Hilcorp Alaska, LLC Project: Duck Island Unit Site: End MPI Well; 2-66 Wellbore: 2-66A Design: 2-66A Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +NIS +EI -W Northing (usft) (1) (•) (usft) (usft) (usft) (usft) (ft) 5,308.00 49.26 233.07 4,475.93 4,435.93 -1,388.61 -1,857.35 5,980,965.23 5,333.00 49.39 233.13 4,492.23 4,452.23 -1,399.99 -1,872.51 5,980,954.34 5,358.00 49.42 233.26 4,508.49 4,468.49 -1,411.37 -1,887.71 5,980,943.46 5,383.00 49.27 233.26 4,524.78 4,484.78 -1,422.71 -1,902.91 5,980,932.61 5,408.00 49.68 233.29 4,541.03 4,501.03 -1,434.07 -1,918.14 5,980,921.74 5,433.00 49.65 233.26 4,557.21 4,517.21 -1,445.47 -1,933.42 5,980,910.85 5,458.00 49.59 233.22 4,573.40 4,533.40 -1,456.87 -1,948.67 5,980,899.95 5,483.00 49.63 233.27 4,589.60 4,549.60 -1,468.26 -1,963.93 5,980,889.05 5,508.00 49.57 233.07 4,605.81 4,565.81 -1,479.67 -1,979.17 5,980,878.13 5,533.00 50.06 232.52 4,621.94 4,581.94 -1,491.22 -1,994.38 5,980,867.08 5,558.00 50.04 231.55 4,637.99 4,597.99 -1,503.01 -2,009.49 5,980,855.78 5,583.00 50.15 231.02 4,654.03 4,614.03 -1,515.01 -2,024.45 5,980,844.28 5,608.00 50.01 230.92 4,670.07 4,630.07 -1,527.08 -2,039.35 5,980,832.69 5,633.00 50.03 231.00 4,686.14 4,646.14 -1,539.15 -2,054.23 5,980,821.11 5,658.00 50.25 230.96 4,702.16 4,662.16 -1,551.23 -2,069.14 5,980,809.51 5,683.00 50.23 231.03 4,718.15 4,678.15 -1,563.32 -2,084.07 5,980,797.91 5,708.00 50.14 231.24 4,734.15 4,694.15 -1,575.37 .2,099.02 5,980,786.34 5,733.00 50.33 231.24 4,750.15 4,710.15 -1,587.40 -2,114.01 5,980,774.80 5,758.00 50.58 231.20 4,766.06 4,726.06 -1,599.48 -2,129.04 5,980,763.22 5,783.00 50.62 231.12 4,781.93 4,741.93 -1,611.59 -2,144.08 5,980,751.59 5,808.00 50.48 231.22 4,797.82 4,757.82 -1,623.70 -2,159.12 5,980,739.98 5,833.00 50.42 231.21 4,813.74 4,773.74 -1,635.77 -2,174.15 5,980,728.40 5,858.00 49.91 231.47 4,829.75 4,789.75 .1,647.77 -2,189.14 5,980,716.89 5,883.00 49.35 231.61 4,845.94 4,805.94 -1,659.61 -2,204.05 5,980,705.53 5,908.00 49.64 231.64 4,862.18 4,822.18 -1,671.41 -2,218.95 5,980,694.22 5,933.00 49.86 231.69 4,878.33 4,838.33 -1,683.25 -2,233.92 5,980,682.87 5,958.00 50.08 231.73 4,894.41 4,854.41 -1,695.11 -2,248.95 5,980,671.50 5,983.00 49.81 231.91 4,910.50 4,870.50 -1,706.94 .2,263.99 5,980,660.16 6,008.00 49.53 232.01 4,926.68 4,886.68 -1,718.68 -2,279.00 5,980,648.91 6,033.00 49.58 231.88 4,942.90 4,902.90 -1,730.41 -2,293.98 5,980,637.67 6,058.00 49.35 231.89 4,959.15 4,919.15 -1,742.14 -2,308.93 5,980,626.43 6,083.00 49.21 231.86 4,975.46 4,935.46 -1,753.84 -2,323.83 5,980,615.22 6,108.00 49.13 231.77 4,991.80 4,951.80 -1,765.53 -2,338.70 5,980,604.01 6,133.00 48.84 231.79 5,008.21 4,968.21 -1,777.20 -2,353.52 5,980,592.82 6,158.00 48.87 231.67 5,024.66 4,984.66 -1,788.86 -2,368.30 5,980,581.64 6,183.00 48.74 231.64 5,041.12 5,001.12 -1,800.53 -2,383.06 5,980,570.45 6,208.00 48.64 231.63 5,057.63 5,017.63 -1,812.19 -2,397.78 5,980,559.28 6,233.00 48.53 231.58 5,074.16 5,034.16 -1,823.83 -2,412.47 5,980,548.11 6,258.00 48.57 231.63 5,090.71 5,050.71 -1,835.47 -2,427.16 5,980,536.95 6,283.00 48.45 231.66 5,107.27 5,067.27 -1,847.09 -2,441.85 5,980,525.81 Well 2-66 2-66A Actual @ 40.00usft 2-66A Actual @ 40.00usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Vertical Easting DLS Section (ft) (-]too-) (ft) Survey Tool Name 256,939.93 1.81 2,260.04 2_Gyro-NS-CT_Csg+Cent (1 256,924.41 0.55 2,278.51 2_Gyr0-NS.CT_Csg+Cent (1 256,908.85 0.41 2,297.01 2_Gyro-NS-CT_Csg+Cenl(1 256,893.30 0.60 2,315.49 2_Gyro-NS-CT_Csg+Cent (1 256,877.71 1.64 2,334.02 2_Gyro-NS-CT_Csg+Cent (1 256,862.08 0.15 2,352.59 2_Gyro-NS-CT_Csg+Cent(1 256,846.46 0.27 2,371.16 2_Gyro.NS-CT_Csg+Cent(1 256,830.85 0.22 2,389.71 2_Gyro-NS-CT_Csg+Cent (1 256,815.25 0.65 2,408.26 2_Gyro-NS-CT_Csg+Cent(1 256,799.67 2.58 2,426.85 2_Gyro-NS-CT_Csg+Cent(1 256,784.19 2.98 2,445.43 2_Gyro-NS-CT_Csg+Cent It 256,768.85 1.68 2,463.96 2_Gyro-NS-CT_CSg+Cent (1 256,753.58 0.64 2,482.47 2_Gyro-NS-CT_Csg+Cent (1 256,738.32 0.26 2,500.95 2_Gyro-NS-CT_Csg+Cent (1 256,723.03 0.89 2,519.47 2_Gyro-NS-CT_Csg+Cent (1 256,707.71 0.23 2,538.02 2_Gyro-NS-CT_Csg+Cent(1 256,692.38 0.74 2,556.57 2_Gyro-NS-CT_Csg+Cent (1 256,677.02 0.76 2,575.13 2_Gyro-NS-CT_Csg+Cent (1 256,661.61 1.01 2,593.76 2_Gyro-NS-CT_Csg+Cent(1 256,646.18 0.29 2,612.42 2_Gyro-NS-CT_Csg+Cenl(1 256,630.76 0.64 2,631.07 2_Gyro-NS-CT_Csg+Cent (1 256,615.35 0.24 2,649.69 2_Gyro-NS-CT_Csg+Cent (1 256,599.99 2.19 2,668.25 2_Gyro-NS-CT_Csg+Cent it 256,584.70 2.28 2,686.68 2_Gyro-NS-CT_Csg+Cent(1 256,569.43 1.16 2,705.08 2_Gyro-NS-CT_Csg+Cent (1 256,554.09 0.89 2,723.55 2_Gyro-NS-CT_Csg+Cent (1 256,538.69 0.89 2,742.08 2_Gyro-NS-CT_Csg+Cent(1 256,523.27 1.21 2,760.62 2_Gyr"S-CT_CSg+Cent(1 256,507.89 1.16 2,779.10 2_Gyro-NS-CT_Csg+Cent (1 256,492.54 0.44 2,797.54 2_Gyro.NS-CT_Csg+Cent (1 256,477.23 0.92 2,815.95 2_Gyro-NS-CT_Cs9+Cant (1 256,461.95 0.57 2,834.31 2_Gyro-NS-CT_Cs9+Cent (1 256,446.71 0.42 2,852.64 2_Gyro-NS-CT_Csg+Cent(I 256,431.53 1.16 2,870.91 2_Gyro-NS-CT_Csg+Cent(1 256,416.38 0.38 2,889.14 2_Gyro-NS-CT_Cs9+Cent(1 256,401.26 0.53 2,907.35 2_Gyro-NS-CT_Csg+Cent (1 256,386.17 0.40 2,925.53 2_Gyro-NS-CT_Csg+Cenl(1 256,371.11 0.46 2,943.68 2_Gyro-NS-CT_Csg+Cent (1 256,356.05 0.22 2,961.81 2_Gyro-NS-CT_Csg+Cent(1 256,341.00 0.49 2,979.94 2_Gyro-NS-CT_C8g+Cent (1 1022018 7:04:19PM Page 8 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Duck Island Unit End MPI 2-66 2-66A 2-66A Local Co-ordinate Reference: Well 2-66 TVD Reference: 2-66A Actual @ 40.00usft MD Reference: 2-66A Actual @ 40.00usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (1) r) (usft) (usft) (usft) (usft) (ft) (ft) (111001) (ft) Survey Too]Name 6,308.00 48.53 231.63 5,123.84 5,083.84 -1,858.71 -2,456.53 5,980,514.67 256,325.96 0.33 2,998.07 2_Gyro-NS-CT_Csg+Cent(1 6,333.00 48.24 231.63 5,140.45 5,100.45 -1,870.31 -2,471.18 5,980,503.55 256,310.94 1.16 3,016.16 2_Gym.NS-CT_Csg+Cent(1 6,358.00 48.24 231.59 5,157.10 5,117.10 -1,881.89 -2,485.80 5,980,49245 256,295.96 0.12 3,034.21 2_Gyro-NS-CT Csg+Cent(1 6,383.00 48.23 231.55 5,173.75 5,133.75 -1,893.48 -2,500.40 5,980,481.33 256,280.98 0.13 3,052.25 2_Gyro-NS-CT_Csg+Cenl(1 6,408.00 48.05 231.51 5,190.43 5,150.43 -1,905.06 -2,514.98 5,980,470.22 256,266.04 0.73 3,070.27 2_Gym-NS-CT_Csg+Cent(1 6,433.00 48.10 231.68 5,207.14 5,167.14 -1,916.62 -2,529.56 5,980,459.15 256,251.10 0.54 3,088.27 2_Gyro-NS-CT_Csg+Cent(1 6,458.00 48.02 231.65 5,223.84 5,183.84 -1,928.15 -2,544.14 5,980,448.09 256,236.15 0.33 3,106.27 2_Gyro-NS-CT_Csg+Cent(1 6,483.00 47.93 231.74 5,240.58 5,200.58 -1,939.66 -2,558.72 5,980,437.05 256,221.22 0.45 3,124.25 2_Gym-NS-CT_Csg+Cent(1 6,508.00 47.96 231.79 5,257.33 5,217.33 -1,951.15 -2,573.30 5,980,426.04 256,206.27 0.19 3,142.23 2_Gyro-NS-CT_Csg+Cent(1 6,533.00 48.25 231.74 5,274.02 5,234.02 -1,962.67 -2,587.92 5,980,415.00 256,191.29 1.17 3,160.26 2_Gyro-NS-CT_Csg+Cent(1 6,558.00 48.17 231.85 5,290.68 5,250.68 -1,974.20 -2,602.56 5,980,403.95 256,176.28 0.46 3,178.31 2_Gyro-NS-CT_Csg+Cent(1 6,583.00 48.60 231.87 5,307.28 5,267.28 -1,985.74 -2,617.26 5,980,392.88 256,161.22 1.72 3,196.42 2_Gym-NS-CT Csg+Cent(1 6,608.00 48.42 231.83 5,323.85 5,283.85 -1,997.31 -2,631.99 5,980,381.80 256,146.13 0.73 3,214.57 2_Gyro-NS-CT Csg+Cent(1 6,633.00 48.28 231.74 5,340.46 5,300.46 -2,008.86 -2,646.67 5,980,370.72 256,131.09 0.62 3,232.66 2_Gym-NS-CT_Csg+Cent(1 6,658.00 48.30 231.65 5,357.09 5,317.09 -2,020.43 -2,661.31 5,980,359.63 256,116.08 0.28 3,250.73 2_Gyro-NS-CT_Csg+Cent(1 6,683.00 48.32 231.63 5,373.72 5,333.72 -2,032.02 -2,675.95 5,980,348.52 256,101.07 0.10 3,268.81 2_Gyro-NS-CT Csg+Cent(1 6,708.00 48.36 231.60 5,390.34 5,350.34 -2,043.62 -2,690.59 5,980,337.40 256,086.07 0.18 3,286.88 2_Gym-NS-CT_Csg+Cent (1 6,733.00 47.93 231.49 5,407.02 5,367.02 -2,055.20 -2,705.17 5,980,326.30 256,071.12 1.75 3,304.90 2_Gyro-NS-CT_Csg+Cent (1 6,758.00 48.01 231.33 5,423.76 5,383.76 -2,066.78 -2,719.69 5,980,315.19 256,056.24 0.57 3,322.86 2 -Gyro -NS -CT Csg+Cent (1 6,783.00 48.18 231.22 5,440.46 5,400.46 -2,078.42 -2,734.20 5,980,304.02 256,041.36 0.75 3,340.84 2_Gyr0-NS-CT_Csg+Cent(1 6,808.00 48.11 231.10 5,457.14 5,417.14 -2,090.10 -2,748.71 5,980,292.82 256,026.49 0.45 3,358.83 2_Gyro-NS-CT_Csg+Cent (1 6,833.00 47.88 230.87 5,473.87 5,433.87 -2,101.79 -2,763.14 5,980,281.59 256,011.69 1.15 3,376.75 2_Gyro-NS-CT_Csg+Cent(1 6,858.00 47.80 230.75 5,490.65 5,450.65 -2,113.50 -2,777.50 5,980,270.35 255,996.95 0.48 3,394.62 2_Gyro-NS-CT_Csg+Cent(1 6,883.00 47.66 230.59 5,507.46 5,467.46 -2,125.23 -2,791.81 5,980,259.09 255,982.27 0.73 3,412.45 2_Gyro-NS-CT_Csg+Cenl(1 6,908.00 47.43 230.46 5,524.34 5,484.34 -2,136.95 -2,806.05 5,980,247.83 255,967.67 1.00 3,430.21 2_Gyro-NS-CT_Csg+Cent (1 6,933.00 48.16 230.35 5,541.13 5,501.13 -2,148.76 -2,820.32 5,980,236.49 255,953.03 2.94 3,448.03 2_Gyro-NS-CT Csg+Cent (1 6,958.00 47.57 230.25 5,557.91 5,517.91 -2,160.60 -2,834.59 5,980,225.12 255,938.39 2.38 3,465.87 2_Gyro-NS-CT_Csg+Cent (1 6,983.00 47.60 230.12 5,574.77 5,534.77 -2,172.42 -2,848.76 5,980,213.76 255,923.84 0.40 3,483.61 2_Gym-NS-CT_Csg+Cent(1 7,008.00 47.53 229.96 5,591.64 5,551.64 -2,184.27 -2,862.91 5,980,202.37 255,909.32 0.55 3,501.33 2_Gyr0-NS-CT_Csg+Cent(1 7,033.00 47.40 229.86 5,608.54 5,568.54 -2,196.13 -2,877.00 5,980,190.97 255,894.86 0.60 3,519.02 2_Gyro-NS-CT_Csg+Cent(1 7,058.00 47.19 229.68 5,625.49 5,585.49 -2,208.00 -2,891.02 5,980,179.56 255,880.46 0.99 3,536.64 2_Gyro-NS-CT_Csg+Cenl(1 7,083.00 47.09 229.58 5,642.50 5,602.50 -2,219.86 -2,904.99 5,980,168.15 255,866.12 0.50 3,554.21 2_Gyro-NS-CT_Csg+Cent(1 7,108.00 46.95 229.47 5,659.54 5,619.54 -2,231.74 -2,918.90 5,980,156.73 255,851.83 0+65 3,571.73 2_Gyro-NS-CT_Csg+Cent(1 7,133.00 46.92 229.33 5,676.61 5,636.61 -2,243.62 -2,932.77 5,980,145.30 255,837.59 0.43 3,589.22 2_Gym-NS-CT_Csg+Cent(1 7,158.00 46.65 229.24 5,693.73 5,653.73 -2,255.51 -2,946.58 5,980,133.86 255,823.40 1.11 3,606.66 2_Gym-NS-CT_Csg+Cent(1 7,183.00 46.38 229.17 5,710.94 5,670.94 -2,267.36 -2,960.31 5,980,122.46 255,809.30 1.10 3,624.01 2_Gym-NS-CT_Csg+Cent(1 7,208.00 46.00 229.21 5,728.24 5,688.24 -2,279.15 -2,973.96 5,980,111.12 255,795.27 1.52 3,641.26 2_Gyn>NS-CT_Csg+Cent(1 7,233.00 46.26 229.08 5,745.57 5,705.57 -2,290.94 -2,987.60 5,980,099.77 255,781.27 1.11 3,658.49 2_Gyro-NS-CT_Csg+Cent(1 7,258.00 46.58 229.17 5,762.80 5,722.80 -2,302.79 -3,001.29 5,980,088.37 255,767.20 1.31 3,675.81 2_Gyro-NS-CT_Csg+Cent(1 7,283.00 46.56 229.28 5,779.99 5,739.99 -2,314.65 -3,015.04 5,980,076.96 255,753.08 0.33 3,693.18 2_Gyro-NS-CT Csg+Cent(1 1022018 7.04:19PM Page 9 COMPASS 5000.1 Build B1E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well 2-66 Project: Duck Island Unit TVD Reference: 2-66A Actual @ 40.00usft Site: End MPI MD Reference: 2-66A Actual @ 40.00usft Well: 2-66 North Reference: True Wellbore: 2-66A Survey Calculation Method: Minimum Curvature Design: 2-66A Database: Sperry EDM - NORTH US + CANADA Survey 102/2018 7:04:19PM Page 10 COMPASS 5000.1 Build 81E Map Map vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) V) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,308.00 46.34 229.20 5,797.21 5,757.21 -2,326.48 -3,028.76 5,980,065.58 255,738.98 0.91 3,710.51 2_Gyro-NS-CT_Csg+Cent (1 7,333.00 45.69 229.27 5,814.57 5,774.57 -2,338.22 -3,042.39 5,980,054.28 255,724.99 2.61 3,727.72 2_Gym-NS-CT_Csg+Cent(1 7,358.00 46.31 229.18 5,831.94 5,791.94 -2,349.97 -3,056.01 5,980,042.98 255,711.00 2.49 3,744.92 2_Gyro-NS-CT_Csg+Cent (1 7,383.00 46.04 229.07 5,849.25 5,809.25 -2,361.77 -3,069,64 5,980,031.62 255,696.99 1.13 3,762.16 2_Gym-NS-CT_Csg+Cent It 7,408.00 45.94 228.86 5,866.62 5,826.62 -2,373.58 -3,083.21 5,980,020.26 255,683.05 0.72 3,779,34 2_Gym-NS-CT_Csg+Cent (1 7,433.00 45.75 228.89 5,884.04 5,844.04 -2,385.37 -3,096.72 5,980,008.90 255,669,17 0.76 3,796.47 2_Gyr0-NS-CT_Csg+Cent(1 7,458.00 45.72 228.73 5,901,49 5,861.49 -2,397.16 -3,110.19 5,979,997.55 255,655.32 0.47 3,813.55 2_Gyro-NS-CT_Csg+Cent(1 7,483.00 45.68 228.51 5,918.95 5,878.95 -2,408.99 -3,123.62 5,979,986.17 255,641.52 0.65 3,830.61 2_Gyro-NS-CT_Csg+Cent It 7,503.00 45.61 228.92 5,932.93 5,892.93 -2,418.43 -3,134.36 5,979,977.08 255,630.48 1.51 3,844.25 2_ MWD_Interp Azi+Sag(2) 7,520.78 46.15 230.98 5,945.31 5,905.31 -2,426.64 -3,144.13 5,979,969.19 255,620.45 8.85 3,856.51 2_ MWD_Interp Azi+Sag(2) 7,549.41 45.27 234.38 5,965.30 5,925.30 -2,439.06 -3,160.42 5,979,957.29 255,603.77 9.04 3,876.43 2 -MWD _Interp Azi+Sag(2) 7,583.14 44.27 238.49 5,989.25 5,949.25 -2,452.20 -3,180.20 5,979,944.80 255,583.58 9.08 3,899.83 2_MWD_Interp Azi+Sag(2) 7,618.86 43.07 242.94 6,015.10 5,975.10 -2,464.26 -3,201.70 5,979,933.44 255,561.71 9,23 3,924.37 2_MWD+IFR2+MS+Sag(3) 7,646.73 42.69 241.65 6,035.52 5,995.52 -2,473.08 -3,218.49 5,979,925.17 255,544.64 3.43 3,943.29 2 MWD+IFR2+MS+Sag (3) 7,710.58 40,71 241.83 6,083.19 6,043.19 -2,493.19 -3,255.90 5,979,906.27 255,506.60 3.11 3,985.64 2_MWD+IFR2+MS+Sag (3) 7,778.19 39.14 240.01 6,135.04 6,095.04 -2,514.27 -3,293.82 5,979,886.42 255,468.02 2.89 4,028.84 2_MWD+IFR2+MS+Sag(3) 7,841.62 35.41 240.71 6,185.50 6,145.50 -2,533.27 -3,327.20 5,979,868.51 255,434.05 5.92 4,067.05 2_MWD+IFR2+MS+Sag(3) 7,905.28 32.67 242.24 6,238.25 6,198.25 -2,550.30 -3,358,49 5,979,852.49 255,402.23 4.51 4,102.56 2_MWD+IFR2+MS+Sag(3) 7,967.87 29.83 244.36 6,291.76 6,251.76 -2,564.91 -3,387.48 5,979,838.83 255,372.78 4.87 4,134.98 2_MWD+IFR2+MS+Sag (3) 8,030.64 27.31 244.80 6,346.88 6,306.88 -2,577.80 -3,414.59 5,979,826.82 255,345.28 4.03 4,164.98 2_MWD+IFR2+MS+Sag(3) 8,095.48 25.15 246.09 6,405.04 6,365.04 -2,589.72 -3,440,65 5,979,815.74 255,318.85 3.45 4,193.64 2_MWD+IFR2+MS+Sag(3) 8,158.71 23.69 247.89 6,462.61 6,422.61 -2,599.94 -3,464.70 5,979,806.30 255,294.48 2.59 4,219.77 2_MWD+IFR2+MS+Sag (3) 8,221.92 22.01 254.52 6,520.87 6,480.87 -2,607.89 -3,487,89 5,979,799.10 255,271.05 4.86 4,244.19 2_MWD+IFR2+MS+Sag(3) 8,285.16 20.72 265.71 6,579.79 6,539.79 -2,611.89 -3,510.47 5,979,795.83 255,248.35 6.75 4,266.47 2_MWD+IFR2+MS+Sag(3) 8,348.40 20.26 274.47 6,639.04 6,599.04 -2,611.87 -3,532.55 5,979,796.56 255,226.28 4.90 4,286.65 2_MWD+IFR2+MS+Sag(3) 8,411.25 19.96 279.32 6,698.06 6,658.06 -2,609.29 -3,553.99 5,979,799.83 255,204.94 2.70 4,305.22 2_MWD+IFR2+MS+Sag (3) 8,474.46 18.28 279.80 6,757.78 6,717.78 -2,605.85 -3,574.40 5,979,803.92 255,184.65 2.67 4,322.51 2_MWD+IFR2+MS+Sag(3) 8,537.56 16.84 284.87 6,817.94 6,777.94 -2,601.82 -3,592.99 5,979,808.55 255,166.20 3.33 4,337.88 2_MWD+IFR2+MS+Sag(3) 8,600.65 15.05 292.56 6,878.61 6,838.61 -2,596.33 -3,609.39 5,979,814.56 255,149,99 4.38 4,350.67 2_MWD+IFR2+MS+Sag(3) 8,663.78 14.59 301.86 6,939.65 6,899.65 -2,588.99 -3,623.72 5,979,822.36 255,135.91 3.83 4,360.80 2_MWD+IFR2+MS+Sag (3) 8,727.43 14.79 310.31 7,001.23 6,961.23 -2,579.50 -3,636.72 5,979,832.26 255,123.21 3.38 4,368.87 2_MWD+IFR2+MS+Sag (3) 8,790.33 14.75 315.55 7,062.05 7,022.05 -2,568.59 -3,648.45 5,979,843.55 255,111.84 2.12 4,375,19 2_MWD+IFR2+MS+Sag(3) 8,853.92 14.75 323.65 7,123.55 7,083.55 -2,556.29 -3,658.92 5,979,856.18 255,101,77 3.24 4,379.79 2_MWD+IFR2+MS+Sag(3) 8,916.63 15.63 330.08 7,184.07 7,144.07 -2,542.54 -3,667.87 5,979,870,21 255,093.28 3.03 4,382.42 2_MWD+IFR2+MS+Sag (3) 8,979.03 15.71 330.42 7,244.16 7,204.16 -2,527.90 -3,676,23 5,979,885.10 255,085.39 0.20 4,384.16 2_MWD+IFR2+MS+Sag(3) 9,042.17 15.55 330.30 7,304.96 7,264.96 -2,513.12 -3,684.64 5,979,900.15 255,077,46 0.26 4,385.88 2_MWD+IFR2+MS+Sag(3) 9,105.03 15.30 330.06 7,365.56 7,325.56 -2,498.61 -3,692.96 5,979,914.92 255,069.61 0.41 4,387.63 2_MWD+IFR2+MS+Sag(3) 9,167,60 14.38 328.42 7,426.04 7,386.04 -2,484.84 -3,701.15 5,979,928.95 255,061.87 1.62 4,389.55 2_MWD+IFR2+MS+Sag(3) 9,223.29 14.56 329.81 7,479.96 7,439.96 -2,472.90 -3,708.29 5,979,941.11 255,055.12 0.70 4,391.26 2_MWD+IFR2+MS+Sag (3) 9,295.27 14.13 328.90 7,549.70 7,509.70 -2,457.55 -3,717.38 5,979,956.74 255,046.53 0.67 4,393.37 2_MWD+IFR2+MS+Sag(3) 102/2018 7:04:19PM Page 10 COMPASS 5000.1 Build 81E Company: Project: Site: Well: Wellbore: Design: Survey Hilcorp Alaska, LLC Duck Island Unit End MPI 2-66 2-66A 2-66A Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2-66 2-66A Actual @ 40.O0usft 2-66A Actual @ 40.00usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,359.07 14.53 328.54 7,611.51 7,571.51 -2,444.06 -3,725.57 5,979,970.49 255,038.77 0.64 4,395.42 2_MWD+IFR2+MS+Sag(3) 9,421.11 14.48 328.02 7,671.58 7,631.58 -2,430.84 -3,733.74 5,979,983.96 255,031.03 0.22 4,397.56 2_MWD+IFR2+MS+Sag(3) 9,484.90 14.78 329.02 7,733.30 7,693.30 -2,417.10 -3,742.16 5,979,997.97 255,023.06 0.61 4,399.70 2_MWD+IFR2+MS+Sag (3) 9,547.77 15.15 329.24 7,794.04 7,754.04 -2,403.17 -3,750.49 5,980,012.16 255,015.19 0.60 4,401.69 2 MWD+IFR2+MS+Sag(3) 9,610.83 15.26 331.23 7,854.89 7,814.89 -2,388.81 -3,758.69 5,980,026.77 255,007.44 0.85 4,403.40 2_MWD+IFR2+MS+Sag(3) 9,674.23 15.00 330.85 7,916.09 7,876.09 -2,374.33 -3,766.71 5,980,041.50 254,999.90 0.44 4,404.88 2_MWD+IFR2+MS+Sag(3) 9,737.39 15.20 330.13 7,977.07 7,937.07 -2,360.01 -3,774.81 5,980,056.07 254,992.26 0.43 4,406.51 2_MWD+IFR2+MS+Sag (3) 9,799.50 15.45 329.46 8,036.97 7,996.97 -2,345.83 -3,783.07 5,980,070.52 254,984.47 0.49 4,408.33 2_MWD+IFR2+MS+Sag(3) 9,862.52 15.34 330.50 8,097.73 8,057.73 -2,331.34 -3,791.44 5,980,085.26 254,976.57 0.47 4,410.13 2_MWD+IFR2+MS+Sag (3) 9,925.12 15.10 330.40 8,158.13 8,118.13 -2,317.05 -3,799.55 5,980,099.81 254,968.93 0.39 4,411.77 2_MWD+IFR2+MS+Sag(3) 9,988.55 15.72 330.36 8,219.28 8,179.28 -2,302.39 -3,807.88 5,980,114.73 254,961.07 0.98 4,413.47 2_MWD+IFR2+MS+Sag(3) 10,051.24 15.31 331.30 8,279.69 8,239.69 -2,287.75 -3,816.05 5,980,129.62 254,953.37 0.77 4,415.03 2_MWD+IFR2+MS+Sag(3) 10,113.54 15.16 329.79 8,339.80 8,299.80 -2,273.50 -3,824.10 5,980,144.13 254,945.79 0.68 4,416.64 2_MWD+IFR2+MS+Sag(3) 10,177.32 15.05 329.65 8,401.38 8,361.38 -2,259.15 -3,832.48 5,980,158.74 254,937.87 0.18 4,418.50 2_MWD+IFR2+MS+Sag(3) 10,240.43 15.89 329.10 8,462.20 8,422.20 -2,244.66 -3,841.06 5,980,173.49 254,929.77 1.35 4,420.50 2_MWD+IFR2+MS+Sag(3) 10,303.56 16.50 327.42 8,522.82 8,482.82 -2,229.69 -3,850.32 5,980,188.75 254,920.99 1.22 4,422.93 2_MWD+IFR2+MS+Sag (3) 10,366.24 15.76 328.65 8,583.04 8,543.04 -2,214.92 -3,859.54 5,980,203.81 254,912.25 1.30 4,425.39 2_MWD+IFR2+MS+Sag (3) 10,429.72 15.99 329.66 8,644.10 8,604.10 -2,200.01 -3,868.45 5,980,219.00 254,903.83 0.57 4,427.51 2_MWD+IFR2+MS+Sag(3) 10,492.55 14.35 329.18 8,704.73 8,664.73 -2,185.86 -3,876.81 5,960,233.42 254,895.93 2.62 4,429.44 2_MWD+IFR2+MS+Sag(3) 10,555.37 13.60 328.35 8,765.69 8,725.69 -2,172.88 -3,884.67 5,980,246.64 254,888.49 1.24 4,431.39 2_MWD+IFR2+MS+Sag (3) 10,619.21 15.06 328.92 8,827.55 8,787.55 -2,159.39 -3,892.89 5,980,260.39 254,880.71 2.30 4,433.46 2_MWD+IFR2+MS+Sag(3) 10,677.30 15.16 330.96 8,883.63 8,843.63 -2,146.29 -3,900.47 5,980,273.73 254,873.55 0.93 4,435.10 2_MWD+IFR2+MS+Sag(3) 10,745.28 15.87 330.07 8,949.13 8,909.13 -2,130.46 -3,909.43 5,980,289.83 254,865.11 1.10 4,436.90 2_MWD+IFR2+MS+Sag(3) 10,808.27 16.10 329.70 9,009.69 8,969.69 -2,115.45 -3,918.13 5,980,305.11 254,856.89 0.40 4,438.80 2_MWD+IFR2+MS+Sag (3) 10,869.41 15.97 329.75 9,068.45 9,028.45 -2,100.87 -3,926.65 5,980,319.96 254,848.85 0.21 4,440.69 2_MWD+IFR2+MS+Sag(3) 10,934.19 16.64 331.06 9,130.62 9,090.62 -2,085.05 -3,935.62 5,980,336.06 254,840.39 1.18 4,442.52 2_MWD+IFR2+MS+Sag(3)M 10,997.32 17.41 330.81 9,190.98 9,150.98 -2,068.90 -3,944.60 5,980,352.49 254,831.94 1.23 4,444.20 2_WD+IFR2+MS+Sag (3) 11,060.65 17.20 330.31 9,251.45 9,211.45 -2,052.49 -3,953.86 5,980,369.19 254,823.21 0.41 4,446.05 2_MWD+IFR2+MS+Sag(3) 11,124.17 16.35 328.54 9,312.26 9,272.26 -2,036.71 -3,963.18 5,980,385.26 254,814.41 1.56 4,448.19 2_MWD+IFR2+MS+Sag(3)M 11,187.61 16.51 327.04 9,373.11 9,333.11 -2,021.53 -3,972.74 5,980,400.74 254,805.33 0.71 4,450.81 2_WD+IFR2+MS+Sag (3) 11,249.35 15.94 329.30 9,432.40 9,392.40 -2,006.88 -3,981.85 5,980,415.68 254,796.71 1.38 4,453.21 2_MWD+IFR2+MS+Sag(3) 11,313.26 16.21 331.79 9,493.81 9,453.81 -1,991.47 -3,990.54 5,980,431.36 254,788.51 1.16 4,454.94 2_MWD+IFR2+MS+Sag(3) 11,377.36 15.24 332.47 9,555.51 9,515.51 -1,976.11 -3,998.67 5,980,446.97 254,780.89 1.54 4,456.17 2_MWD+IFR2+MS+Sag(3) 11,440.64 15.61 333.33 9,616.51 9,576.51 -1,961.13 -4,006.33 5,980,462.19 254,773.71 0.69 4,457.13 2_MWD+IFR2+MS+Sag (3) 11,503.67 16.49 332.13 9,677.08 9,637.08 -1,945.64 -4,014.32 5,980,477.92 254,766.22 1.49 4,458.18 2 MWD+IFR2+MS+Sag(3) 11,566.87 16.34 331.15 9,737.70 9,697.70 -1,929.93 -4,022.80 5,980,493.90 254,758.25 0.50 4,459.59 2_MWD+IFR2+MS+Sag(3) 11,630.17 16.34 328.85 9,798.45 9,758.45 -1,914.51 4,031.71 5,980,509.60 254,749.85 1.02 4,461.50 2_MWD+IFR2+MS+Sag(3) 11,693.18 15.54 329.16 9,859.04 9,819.04 -1,899.68 -4,040.62 5,980,524.71 254,741.42 1.28 4,463.66 2_MWD+IFR2+MS+Sag (3) 11,756.95 16.50 330.33 9,920.33 9,880.33 -1,884.47 4,049.48 5,980,540.19 254,733.05 1.59 4,465.63 2_MWD+IFR2+MS+Sag (3) 11,819.99 16.37 330.92 9,980.79 9,940.79 -1,868.93 4,058.23 5,980,556.01 254,724.81 0.34 4,467.35 2_MWD+IFR2+MS+Sag (3) 1022018 7:04.19PM Page 11 COMPASS 5000.1 Build 8fE Company: Hilcorp Alaska, LLC Project: Duck Island Unit Site: End MPI Well: 2-66 Welfbore: 2-66A Design: 2-66A Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2-66 2-66A Actual @ 40.00usft 2-66A Actual @ 40.00usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Checked By: Chelsea Wright. Approved By: Mitch Laird m — Date: 10-02-2018 1022018 7:04:19PM Page 12 COMPASS 5000.1 Build 81E Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El -W Northing Easting DLS Section (usft) (°) (") (usft) (usft) (usft) (usft) (ft) (ft) ("1100') (ft) Survey Tool Name 11,882.70 16.10 329.41 10,041.00 10,001.00 -1,853.72 -4,066.95 5,980,571.49 254,716.58 0.80 4,469.16 2_MWD+IFR2+MS+Sag (3) 11,946.34 16.05 327.46 10,102.15 10,062.15 -1,838.71 -4,076.17 5,980,586.79 254,707.85 0.85 4,471.55 2_MWD+IFR2+MS+Sag(3) 12,010.10 15.90 326.52 10,163.45 10,123.45 -1,823.99 -4,085.73 5,980,601.80 254,698.77 0.47 4,474.35 2_MWD+IFR2+MS+Sag(3) 12,071.37 15.64 327.20 10,222.42 10,182.42 -1,810.05 -4,094.83 5,980,616.03 254,690.12 0.52 4,477.05 2_MWD+IFR2+MS+Sag (3) 12,136.25 15.66 327.73 10,284.89 10,244.89 -1,795.30 -4,104.25 5,980,631.08 254,681.19 0.22 4,479.70 2 MWD+IFR2+MS+Sag(3) 12,166.60 15.20 328.70 10,314.15 10,274.15 -1,788.43 -4,108.50 5,980,638.08 254,677.15 1.74 4,480.81 2_MWD+IFR2+MS+Sag(3) 12,193.00 15.20 328.70 10,339.62 10,299.62 -1,782.52 -4,112.10 5,980,644.11 254,673.75 0.00 4,481.71 PROJECTED to TD Checked By: Chelsea Wright. Approved By: Mitch Laird m — Date: 10-02-2018 1022018 7:04:19PM Page 12 COMPASS 5000.1 Build 81E THE STATE 01ALASKA GOVERNOR BILL WALKER Bo York Operation Manager 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.00gcc.olaska.gov Re: Endicott Oil Field, Endicott and Seabee Undefined Oil Pool, DIU MPI 2-66A Permit to Drill Number: 218-106 Sundry Number: 318-465 Dear Mr. York: 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, Hollis S. French Chair DATED this t4 day of October, 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AA(. 75 9An 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ 10,i Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 ' Re-enter Susp Well ❑ Alter Casing ❑ Other:. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 218-106 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22374-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No 0 DIU MPI 2-66A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL034633 - Endicott Field / Endicott Oil & Seabee Undefined Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,193' 10,340' 12,193' 10,340' 3,304 12,057' 11,554' Casing Length Size MD TVD Burst Collapse Conductor 134' 20" 161' 161' N/A N/A Surface 2,845 13-3/8" 2,872' 2,739' 5,020psi 2,260psi Production 7,503' 9-5/8" 7,503' 5,933' 6,870psi 4,760psi Liner 5,892' 17" 112,183' 110,330' 10,160psi 10,540psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.3# / 13Cr / JFE Bear 11,595 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 6,291MD/ 5,2113TVD, 10,311 MD/ 8,530TVD & 11,469MD/ 9,644ZTVD 9-5/8" x 7" LTP & (2) T' X 3.5" PHL and TRMAXX SSSV and 1,517MD/ 1,513TVD 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/23/2018 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: Bo York Contact Name: Taylor Wellman Authorized Title: Operatio anager Contact Email: twellman hilcor .com T v.s2 A..l Contact Phone: 777-8449 Authorized Signature. uS2 db Y-9Date: 10/12/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: // I U (0 I� /✓� Plug Integrity ❑ BOP Test E] Mechanical Integrity Test ❑ Location Clearance ❑ I Other: o w"A,IU Prt1d1v0 O,P v/GAl {7 I- �v,Y/avr O/der Of Ad B cG � 171g1� Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDM' OCA L Spacing Exception Required? Yes ❑ No Subsequent Form Required: ._ L-1 0 ' APPROVED BY te- Approved by: COMMISSIONER THE COMMISSION Date: IO K-4 Ike- Jv r "1' i8�1�"f"� A�. Submit Form and .411 FoNJI, 3 Revised 4/2017 Approved applicatio is i f r fr a date of approval. Attachments in Duplicate K Hilmrp Alaska, M Post Sidetrack Work Well: END 2-66A PTD: 218-106 API: 50-029-22374-01 Well Name: END 2-66A API Number: 50-029-22374-01 Current Status: Shut in — Post sidetrack Rig: SL/EL Estimated Start Date: October 23, 2018 Estimated Duration: 3 day Reg.ApprovalReq'std? Yes Date Reg. ApprovalRec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 218-081 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: 1811485C WeIIEZ Entry Required? Yes Current Bottom Hole Pressure: 4,165 psi @ 8,613' TVD (Estimated off of brine wt during perforating) Maximum Expected BHP: 4,165 psi @ 8,613' TVD (Estimated off of brine wt during perforating) Max Predicted Surface Pressure: 3,304 psi (Max Expected BHP — (.1 psi/ft * 10000 ft)) Max Deviation: 51.8 deg at 4,458' and Minimum ID: 2.75" XN Nipple @ 11,554' and Brief Well Summary: The Endicott 2-66A has recently been sidetracked to a new bottomhole location. A new zone was encountered and the completion design was altered to accommodate flowing either the new zone (Fenris Zone eabee Undefined Oil Pool) or the Kekituk sands separately. Objective: 1. Install gas lift design 2. Flow test Fenris zone & obtain diagnostics: PBU & downhole sample 3. Isolate the Fenris zone 4. Perforate and produce the FIV & FV sands Procedure: No sundry required to proceed with the initial steps (see note below when sundried operations begin) Slickline 1. RU SL unit. Pressure test PCE to 250psi low / 3,500psi high. 2. Pull RHC plug body from XN nipple at 11,554' md. l 3. MU 20' dummy gun drift and drift tubing down to the PBTD. 4. Pull DGLV's from Sta #6 at 4,095' and and Sta #5 at 6,970' md. a. Setting of catcher sub at WSM's discretion. 5. Set LGLV's in Sta #5 & 6 as per GL design pull/run sheet. 6. Shift the 3-1/2" sliding sleeve at 10,363' and open. a. Halliburton SSD is an XD (down to open). 7. Set downhole pressure/temp gauges in the X -Nipple at 10,270' md. a. Press/Temp Gauge Settings: 1 sample/2 second (primary gauge) and 1 sample/5 seconds (backup gauge). 8. RD SL unit. Operations 00"J )CAM"' 9. Bring well online witgaslift as per RP for Gas Lift Unloading Procedure. Shut in gas lift once well is online and flowing on its own. 10. Flow test well for a period of 3-4 days, unless otherwise directed by the Ops Engineer. K Ililwrp Alaska, LU Post Sidetrack Work Well: END 2-66A PTD: 218-106 API: 50-029-22374-01 11. Shut in well to begin PBU (Pressure Build Up). a. Shut in well with the closest valve to the wellhead as safely possible (SSV recommended). Closing valves downstream of this is recommended for securing well but do not close any valves upstream of this point. Block in the control line pressure so that it does not bleed off and close. Changing the volume of the tubing will affect the downhole pressure being recorded and could impact the PBU results. Contact Ops Engineer for further discussion as needed. Slickline 12. RU SL unit. Pressure test PCE to 250psi low / x,xxx psi high. a. High pressure test pressure to be determined by final SIWHP. This will be approximately 200psi above SIWHP. 13. RIH and pull BHP gauges. 14. MU & run downhole sampling tools. Once sitting above the DH gauges, open choke to minimum opening and allow well to produce—10bbls. Sample tool should shut on timer. Shut in well and POOH. 15. Confirm recovered sample and transfer to shipping containers. Contingency (if proceeding to perforate the FIV & FV sands): 16. RIH and shift sliding sleeve at 10,363' and shut. 17. Use GL pressure to pressure up on tbg to confirm shut. 18. RD SL unit. Operations 19. Apply gaslift to the IA to circulate out fluid from the s/o valve at 6,970' md. a. Shoot FL shots to confirm tbg FL is at this GLM. 20. Bleed down the IA and tubing pressure to 500psi. E -Line 21. RU EL unit and pressure test PCE to 250psi low/ x,xxx psi high. a. High pressure test pressure to be determined by final SIWHP. This will be approximately 200psi above SIWHP. 22. MU TMD -31) Toolstring. RIH and log as per the following table. Logging Summary for END2-66A Pass Direction Seed Depths (MD) Notes TMD3D—Si ma Mode UP —15f m TD—±11,700' In7"casing_ TMD3D —Sigma Mode UP —15 fpm ±10,500 —±10,300' Behind 3-1/2" tbg & 7" csg. Annulus will be hydrocarbon liquid filled TMD3D —Sigma Mode UP —15 fpm Repeat sections ss needed by Toolhand a. Ensure that pressure/temperature data is displayed on the log and the WHP listed in the comments section. Post Sidetrack Work Well: END 2-66A PTD: 218-106 Hik rnAlaska, LI) API: 50-029-22374-01 b. Send log to: Ops Engineer (twellman@hilcorp.com), Chris Kanyer (ckanver@hilcorp.com) and Daniel Yancey dyancey@hilcorp.com for review prior to proceeding with perforating. M Steps beyond this point are require an approved Sundry. Do not proceed without this in hand. 23. MU perforating toolstring and RIH. a. Perf guns to be used: 2" to 2-1/2", 6-12spf, 60 deg phasing with deep penetrating charges. Run # Perf Top Perf Bottom Perf Length Formation Carrier/Charge/Note 1 ±11,911' ±11,931' 20' FIV Shooting -1,000psi underblanced 2 ±11,905' ±11,911' 6' FIV 3 ±11,839' ±11,857' 18' FV Total 44' Table 1: Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Note2: Gun Runs #1&2 may be combined into a single gun run based upon drifts & WSM discretion. 24. Correlate and perforate for Run #1 as in Table 1: Proposed Perf Gun Runs. a. These will be perforate 7un erbalanced. Target is to be I,000psi under. The anticipated BHP of the FIV and FV sands are 4,250psi @ 10,000'tvd. Contact Ops Engineer to determine appropriate WHP to be held on tbg for underbalance. WHP to be determined by the BHP from the TMD -3D logging run. b. Correlation log to be used: TMD -31) Log previously ran above. c. Note any pressure changes in the report. 25. MU and perforate �911A2 as in Table 1: Proposed Perf Gun Runs. 26. POOH and RD E -Line unit. Operations 27. Flow test well from the FIV sands for a period of-7days. E -Line 28. RU EL unit and pressure test PCE to 250psi low/3,250psi high. 29. MU perforating toolstring and RIH. b. Perf guns to be used: 2-7/8" to 3-1/8", 6-12spf, 60 deg phasing with deep penetrating charges. 30. Correlate and perforate for Run #3 as in Table 1: Proposed Perf Gun Runs. 31. POOH and RD E -Line unit. K Hilcorp Alaskp, LLC KB Hev.: 0/ BF/GL Elev.:13.3' 2a'eA 133/.8 a SCHEMATIC Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD H25 Readings Average 230-260 PPM on A/L & Gas Injectors Tree 4-1/16" CIW Well hasa SSSV Wellhead CIW OPEN HOLE / CEMENT DETAIL 13-3/8" 4,557 cu/ft Permafrost in 17.5" Hole 9-5/8" 575 cu/ftClass'G' in a 12-1/4" Hole 7„ Stg 1126 sx of 14.5 ppg Class G-30 BBLS Stg 2111 sx of 15.8 ppg Class G-23 BBLS CASING DETAIL a Depth Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 161' N/A 13-3/8" Surface 68/N-80/Btrs 12.415 Surface 2,872' 0.150 9-5/8" Production 47/NTSOS/NSCC 8.681 Surface 7,503' 0.0732 7" Liner 26/L-80/DWC 6.184 6,291' 12,183' 0.0372 266 Abandoixled Nkllbore 9 7" Stage Tool @ 10,547 ND Min IR2.75" @ 11,559' TUBING DETAIL a&s 3-1/2" Tubing 9.3/13Cr/JFE Bear 2.992 Surface 11,595 0.0087 35/8' WELL INCLINATION DETAIL Window Max Hole Angle = 51.8 deg. @ 4,458' 7' Angle at Top Perf =15 Deg. @ 10,395' JEWELRY DETAIL 7- TD= ]2,193' (ND) /TD=10,340'(JVD) PBTD=12,057' (ND) / PBID=10,2WMJD) No Depth Item 1 1,517' 3.5"SUB -TRMAXX SSSVw/X-Nip le-ID=2.813" 30' 10/3/18 Open 3-3/8" GLM DETAIL: SLB - SPM -1-1/2" w/ RK Latch 2 4,095' STAB: Patco-Dev=,VLV= SOV, IA Shear 2500psi, Port= 0, TVD=3698', Date= 3 6,970' STAS: Patco-Dev=,VLV= DMY, Port -0, TVD=5566', Date= 4 6,291' 9-5/8"x7" i-inerTop Packer 5 6,306' 9-5/8"x7" Liner Hanger 6 8,294' STA 4: Patco- Dev=, VLV= DMY, Port= 0, TVD= 6588', Date= 7 9,088' STA 3: Patco- Dev=, VLV= DMY, Port= 0, TVD= 7349', Date= 8 9,888' STA 2: Patco - Dev=, VLV= DMY, Port= 0, TVD= 8122', Date= 9 10,191' STA 1: Patco-Dev=,VLV=DMY, Port= 0, TVD=8415', Date - 10 10,270' 3-1/2"HES -X Nipple - ID= 2.813" 11 10,311' 7" x 3-1/2" HES PHL Packer 12 1 10,363' 3-1/2" Sliding Sleeve (0=2.813") 13 11,469' 7" x 3-1/2" HES PHL Packer 14 11,514' 3-1/2"HES -XNipple -ID 2.813" 15 11,554' 1 3-1/2"HES -XN Nipple - ID= 2.75" 16 11,594' 1 3-1/2"WLEG-ID= 2.992"-Btm @11,595' PERFORATION DETAIL ENDSands Top (MD) Btm (MD) Top (TVD) Btm (ND) FT Date Status Size Undefined 10,395' 10,405' 8,610' 8,620' 30' 10/3/18 Open 3-3/8" UPS2 TBD Reference Perf Log: GE NERAL WELL I N FO API: 50-029-22374-01-00 Initial Completion -10/1/1983 Revised By: CID 10/09/2018 K corn Alaska. LLC KB Bev.: 49/ BF/GL Elev.: 13.3' PROPOSED SCHEMATIC TD=12,193' (ND) / TD=10,34UVVD) PBTD=12,057 (ND)/PBM =10,208'RVD) Duck Island Unit Well: END 2-66A Last Completed: 10/07/2018 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD H25 Readin s Average 230-260 PPM on A/L & Gas Injectors Tree 1 4-1/16" CIW Well has a SSSV Wellhead I CIW OPEN HOLE/ CEMENT DETAIL 13-3/8" 4,557 cu/ft Permafrost in 17.5" Hole 9-5/8" 575 ,/it Class'G' in a 12-1/4" Hole 7„ Stg 1126sxof 14.5 ppg ClassG-30BBLS St: 2111sx ofl5.8 ClassG-238BLS CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 161' N/A 13-3/8" Surface 68/N-80/Btrs 12.415 Surface 2,872' 0.150 9-5/8" Production 47/NT805/NSCC 8.681 Surface 7,503' 0.0732 7" Liner 26/L-80/DWC 6.184 6,291' 12,183' 0.0372 TUBING DETAIL 3-1/2" Tubing 9.3/13Cr/JFE Bear 1 2.992 1 Surface 1 11,595 0.0087 WELL INCLINATION DETAIL Max Hole Angle = 51.8 deg. @ 4,458' Angle at Top Perf= 15 Deg. @ 10,395' JEWELRY DETAIL No Depth Item 1 1,517' 3.5"SUB- TRMAXX SSSVw/X-Ni le-ID=2.813" END Sands GLM DETAIL: SLB - SPM -1-1/2' w/ RK Latch 2 4,095' STA 6: Patco - Dev=, VLV= SOV, IA Shear 2500 psi, Port= 0, TVD=3698', Date= 3 6,970' STA 5: Patco- Dev=, VLV= DMY, Port-- 0, TVD=5566', Date= 4 6,291' 9-5/8"x7" Liner Top Packer 5 6,306' 9-5/8"x7" Liner Hanger 6 8,294' STA 4: Patco-Dev=,VLV= DMY, Port= 0, TVD=658€',Date= 7 9,088' STA 3: Patco-Dev=,VLV= DMY, Port= 0, TVD=7349', Date- Future 9,888' STA 2: Patco-Dev=,VLV= DMY, Port= 0, TVD=8122', Date - -8 9 10,191' STA 1: Patco- Dev=, VLV= DMY, Port= 0, TVD= 8415', Date= 10 10,270' 3-1/2"HES -X Nipple - I D= 2.813" 11 10,311' 7" x 3-1/2" HES PHL Packer 12 10,363' 3-1/2- Sliding Sleeve ID=2.813" 13 11,469' 7"x3-1/2"HES PHL Packer 14 11,514' 3-1/2"HES -XNipple -ID 2.813" 15 11,554' 3-1/2"HES -XN Nipple -ID=2.75" 16 11,594' 3-1/2"WLEG-ID= 2.992"-Btm@11,595' GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion -10/1/1983 Revised By: TTW 10/10/2018 PERFORATION DETAIL END Sands Top (MD) Btm(MD) TOP (TVD) Stm(TVD) Fr Date Status Size Undefined 10,395' 10,405' 8,610' 8,620' 10' 10/3/18 Open 3-3/8" FV 3 18' Future Future FIV 2 ±11,905' ±11,931' 26' 1 Future Future Reference Perf Log: GENERAL WELL INFO API: 50-029-22374-01-00 Initial Completion -10/1/1983 Revised By: TTW 10/10/2018 THE STATE GOVERNOR BILL WALKER Monty Myers Drilling Manager Hilemp 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.alaska.gov Re: Endicott Field, Endicott and Seabee Undefined Oil Pools, DIU MPI 2-66A Permit to Drill Number: 218-106 Sundry Number: 318-430 Dear Mr. Myers: 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. DATED this C1� day of September, 2018. Sincerely, CathjPoeprster Commissioner RBDMS5t- OCT 0 2 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 °IED cep 2 6 2C' 1. Type of Request: Abandon ❑ Ph -q Perforations ❑ Fracture Stimulate E] Repair -Well 1:1 Operations shutdown❑ Suspend B /y f,0 Perforate (JOther Stimulate ❑ Pull Tubing ❑ Change A ved Program ❑� S Plug for Redrill ❑ Perforate New Pool Re-enter Sus Well p ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑Q StratigraphiService c El❑ 218-106 ' 3. Address: 6. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-029-22374-01-00 7. If perforating: -�cf 4 ; C j 7 Zo 2,S• �:SS� 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 ❑Q DIU MPI 2-66A 9. Property Designation (Lease Number): 10. Field/Pool(s):`��� ADLO34633 Endicott Field 1f. PRESENT WELL CONDITION SUMMARY j 7- l? Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,193' 10,340' 12,193' 10,340' 3496 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 134' 20" 161' 161' Surface 2,845 13-3/8" 2,872' 2,739' 5020 psi 2260 psi Intermediate 7,503' 9-5/8" 7,503' 5,933' 6870 psi 4760 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary ❑Q Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development BQ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/28/2018 OIL ❑Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Yes - Email Date: 9/25/2018 Commission Representative: Guy Schwartz 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: Monty Myers Contact Name: Joe Engel Authorized Title: Drilling Manager Contact Email: jgn el hi cor .Colin 17/(L rMa NT MY� Contact Phone: 777-8395 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: NoftlCommission so that a representative may witness Sundry Number: �J I 30 /,r {✓-J `%J^U Plug Integrity ❑ BOP Test [� Mechanical Integrity Test ❑ Location Clearance ❑ /� p Other. .y(- J30 '' s r {..1 yooD psi X- �L, Post Initial Injection MIT Req'd? Yes ❑ No ❑, Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: APPROVED BY Approved by: ( COMMISSIONER THE COMMISSION Date: 7 /9 (:� j.�l I NAL RBDMS�CT 0 2 2018 Submit Form and Form 10-403 Revised 4/2017 Appr ved applicatio rs va i for 12 months from the date of approval, ttachments in Duplicate ,-,'K fa % y7 -/S U Ililrn" AIuA.' LLC Hilcorp End 2-66A-9.26.2018 2 Stage Liner Cement Job Sundry Outline Purpose: Due to encountering an unexpected hydrocarbon bearing zone, a 2 stage cement job will be performed on 2-66A. This outline will replqce steps in the section 18.0 of the approved drilling program. Wi Program Outline: ,2 5TACL • LD RSS BHA • Perform 8.5" Cleanout run to TD • Run 7" 26# DWC Liner to TD • C&C Mud for Cement Job • Pump 111 stage Cement Job o D: 12,193' MD o Top Kekiktuk FV: 11,840' MD — o Planned TOC: 11,340' MD o Cement Density: 14.5 ppg o Cement Volume: 27 bbl (Includes 40% OH Excess) • Land V stage plug • Increase Pressure and open stage cementer • C&C mud for cementjob • Pump 2nd Stage Cement Job \ o Stage Tool Depth: 10,558' MD WESJ o Top Hydorcarbon Zone 10,392' MD o Planned TOC: 9,892' MD c,� o Cement Density: 15.8 ppg o Cement Volume: 21bbl • Land 2nd stage plug & t C 'J • Increase pressure and close stage tool • Set Liner Hanger (Liner hanger may be set before cement job pending stage cement pressures) • Pressure Test 7" Liner 0 3000 psi for 30 min o Chart Test • Set Liner Top Packer • CBU 0 POOH H I il"rp M.A., LLC Updated Clean out and 3.5" Completion Outline Purpose: Due to the unexpected hydrocarbon zone, we will perform CBL across both cemented intervals as well as change the completion to run straddle packers with a sliding sleeve in between across the perforation interval of the new hydrocarbon zone. The revised completion will allow for testing/producing from the zone while maintaining isolated from the Kekituk pool.* Completion changes can be seen on the attached schematic. Perform 7" Cleanout Run & 7" CBL • Perform 7" cleanout run to mill stage collar • Perform 7" scraper run & displace to 9.0 ppg brine • RU EL • Run CBL o Ensure cement has reached 2000psi compressive strength o Run CBL from PBTD to 500' above planned TOC of both cement stages • Perforate 10,393'— 10,403' (10') A L • POOH & RD EL • Perform 7" scraper run across perforations Run 3-1/2" Upper Completion • Run 3-1/2" Upper completion • Spot packer fluid • Drop ball & rod and pressure up on tubing to 3000psi for 30min. Pressure up to 3500psi to set packers. • Test annulus to 3000psi, bleed down pressures. • RU SL and pull ball & rod • Test down tubing to 2500psi for 30min (tests underside of lower packer) • Pressure annulus and bleed tubing to shear out SOV • Install TWC and ND BOP PROP' )ED SCHEMATIC Duck Island Unit Well: END 2-66A if Rev1 Last Completed: xx/xx/xxxx ElilcorP Alaska, I.I.0 PTD: 218-106 SAFETY NOTES TREE & WELLHEAD KB Elev.: 41.5/ BF Elev.: 15' 1-12S Readings Average 230-260 PPM on A/L &Gas Injectors Tree 1 4-1/16" CIW 20" 6tjWell Requiresa SSSV Wellhead I CIW OPEN HOLE / CEMENT DETAIL 2 3 ss/s" 6 2-66 Abandonded Wellbore 7'Stage Tool @10,558' MD Mn 122.75" @±11,560" a 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top cu/k Permafrost in 17.5" Hole BPF 20" Conductor N/A/N/A/N/A N/A Surface 9-5/8" 1 575 cu/ft Class'G' in a 12-1/4" Hole 7" Stg 1-27 bb1s/Stg221 bbis 68/N-80/Burs 12.415 Surface 2,872' 0.150 2 3 ss/s" 6 2-66 Abandonded Wellbore 7'Stage Tool @10,558' MD Mn 122.75" @±11,560" a 9 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface 161' N/A 13-3/8" Surface 68/N-80/Burs 12.415 Surface 2,872' 0.150 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 7,503' 0.0732 7" Liner 26/L-80/DWC 6.184 ±7,350' ±12,193' 0.0372 TUBING DETAIL 3-1/2" Tubing 9.3/13Cr/1FE Bear 1 2.992 1 Surface 1 ±11,600 1 0.0087 WELL INCLINATION DETAIL 4ss Max Hole Angle = TBD 9-5/8' TOW. Angle at lop Perf= TBD 7,503' VVID JEWELRY DETAIL 11 12 f�u 13 - 14 No Depth Item 1 ±1,500' 3.5"SLB-TRMAXXSSSVw/X-Nip le-ID=2.813" GLM DETAIL: SLB - SPM -1-1/2" w/ RK Latch 2 ±4,085' STA 6: Patco - Dev=, VLV= DMY, Port= 0, TVD=', Date= 3 ±6,985' STA 5: Patco - Dev=, VLV= DMV, Port= 0, TVD=', Date= 4 ±7,500' 9-5/8"x7" Liner Top Packer 5 ±7,510' 9-5/8"0" Liner Hanger 6 ±8,300' STA 4: Patco - Dev=, VLV= DMV, Port= 0, TVD--', Date= 7 ±9,100' STA 3: Patco - Dev=, VLV= DMY, Port= 0, TVD=', Date= 8 ±9,900' STA 2: Patco - Dev=, VLV= DMY, Port= 0, TVD=', Date= 9 ±10,700' STA 1: Patco - Dev=, VLV= DMV, Port=0, TVD=', Date= 10 ±11,450' 3-1/2"HES -X Nipple — ID= 2.813" 11 ±10,310' 7" x 3-1/2" HES PHL Packer 12 ±10,454 3-1/2" Sliding Sleeve (ID=2.813"), Shifting Tool= 13 ±11,494 7" x 3-1/2" HES PHL Packer 14 ±11,524 3-1/2" HES - X Nipple — ID 2.813" 15 ±11,564 3-1/2"HES -XN Nipple — I D= 2.75" 16 ±11,604 3-1/2"WLEG—ID=2.992"—Btm@11,602' PERFORATION DETAIL t- AJef dw i le— C su tf-:y TD=12,193'(MD)/Tl) =10,340'(TVD)-'z7:/S PBTD =±12,104 (MD) / P91D=±10,280 M) GENERAL WELL INFO API: 50-029-22374-03-00 Initial Completion -10/1/1983 Revised By: UD 09/26/2018 END 2-66A Sidetrack uw....u..�,. u.c Updated 2 Stage 7" Liner Cement Job — With Actual TD/Depths 9.26.2018 7" Liner Top: 6,317'MD/ 5,125- TVD 9-5/8" Window: 7,500' MD / 5,930' ND 2nd Stage TOC: 9,892' MD Volume (incl 40% OH Excess): 21 bbl Stage Tool Depth: 10558' MD 1" Stage TOC: 11,340' MD volume (incl 40% OH Excess): 27 bbl 7"12,193' MD / 10,340' ND 2-66 Abandoned Parent Bore Formation Description Schrader/West C. • •-. Oil- Reservoir— I Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 25, 2018 2:50 PM To: 'Joe Engel' Cc: Taylor Wellman; Paul Mazzolini; Monty Myers; Boyer, David L (DOA); Cody Dinger Subject: RE: [EXTERNAL] RE: Hilcorp End MPI 2-66A (PTD# 218-106) Update Joe, You have verbal approval to proceed with the stage collar installation and pumping a 2nd stage to cover the upper new hydrocarbon zone 10393 ft. md. Cementing details need to be included in the sundry application. Update MOC also. 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 aov). From: Joe Engel <jengel@hilcorp.com> Sent: Tuesday, September 25, 2018 2:21 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Paul Mazzolini <pmazzolini@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Boyer, David L (DOA) <david.boyer2@alaska.gov>; Cody Dinger <cdinger@hilcorp.com> Subject: RE: [EXTERNAL] RE: Hilcorp End MPI 2-66A (PTD# 218-106) Update Thank you, Guy. We will submit a sundry ASAP. May we get verbal approval to proceed, prior to submitting the sundry? Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 ( Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 From: Schwartz, Guy L (DOA) [mailto•euy.schwartz@alaska.aovI Sent: Tuesday, September 25, 2018 2:10 PM To: Joe Engel <ieneel@hilcorp.com> Cc: Taylor Wellman <twellman hilcorp.com>; Paul Mazzolini <pmazzolini@hilcorp com>; Monty Myers <mmyers@hilcorp.com>; Boyer, David t (DOA) <david boyer2@alaska.gov> Subject: [EXTERNAL] RE: Hilcorp End MPI 2-66A (PTD# 218-106) Update Joe, Will need a sundry to capture the new cementing plan. We 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.aov(. From: Joe Engel <iengel@hilcorp.com> Sent: Tuesday, September 25, 2018 2:00 PM To: Schwartz, Guy L (DOA) <guy Schwartz@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Paul Mazzolini <pmazzolini@hilcorp.com>; Monty Myers <mmyers@hilcorp.com> Subject: RE: Hilcorp End MPI 2-66A (PTD# 218-106) Update Hello Guy — I wanted to give you an update on our plan forward for cementing the newly encountered hydrocarbon bearing zone on End 2-66A. We were able to source a 7" liner compatible stage cementer and plug set, and will be able to complete the well as permitted with a 7" liner while also cementing both hydrocarbon bearing zones. Please see the attached well design drawing as reference. I have update the MOC. Please let me know if a sundry will be required. Current operations on 2-66A: Drilling 8.5" hole section at 11,300' MD Thank you for your time. Please let me know if you have any questions. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 ) Anchorage ) AK ) 99503 Office: 907.777.8395 1 Cell: 805.235.6265 From: Joe Engel Sent: Monday, September 24, 2018 6:38 PM To: Guy Schwartz (guy schwartz@alaska.gov) <guy.schwartz@alaska.Rov> Cc: Taylor Wellman <twellman@hilcorp.com>; Paul Mazzolini <pmazzohni@hilcorp.com>; Monty Myers <mmyers@hi Icorp.com> Subject: Hilcorp End MPI 2-66A (PTD# 218-106) Update Hello Guy — I wanted to give you an update on End 2-66A sidetrack and a follow-up email to our earlier phone conversation. While drilling ahead in the 8.5" hole section, we encountered a hydrocarbon bearing zone that we had not previously known about, Top: 10,393' MD Bottom (lowest possible): 10,450' MD (OH log attached for reference). Since this zone will need to be cemented, we are looking at well design options to allow us to do so. Our first option would be a two stage 7" liner cement job, however we are currently attempting to source necessary equipment to be able to purse it. If we are unable to perform a two stage 7" liner cement job, then we will top set our 7" liner at 10,900' MD, cement this new zone, and then drill a 6-1/8" hole section to planned TO of - 12,092' MD, and run and cement a 4- 1/2" liner as per the contingency liner option in the approved program, section 20. Both of these options will allow us to set our liner top at 6317' MD, above the leak in the 9-5/8" casing as per prior approval. I will let you know what option we will be pursuing once it is determined. As per our conversation, a sundry will be submitted. Thank you for your time. Please let me know if you have any questions. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 Davies, Stephen F (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, September 25, 2018 8:35 AM To: Roby, David S (DOA); Boyer, David L (DOA); Davies, Stephen F (DOA) Subject: FW: Hilcorp End MPI 2-66A (PTD# 218-106) Update Attachments: HAK End 2-66A OH Log.pptx FYI... will need a sundry to modify the PTD 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@aloska aov). From: Joe Engel <jengel@hilcorp.com> Sent: Monday, September 24, 2018 6:38 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Paul Mazzolini <pmazzolini@hilcorp.com>; Monty Myers <mmyers@hilcorp.com> Subject: Hilcorp End MPI 2-66A (PTD# 218-106) Update Hello Guy — I wanted to give you an update on End 2-66A sidetrack and a follow-up email to our earlier phone conversation. While drilling ahead in the 8.5" hole section, we encountered a hydrocarbon bearing zone that we had not previously known about, Top: 10,393' MD Bottom (lowest possible): 10,450' MD (OH log attached for reference). Since this zone will need to be cemented, we are looking at well design options to allow us to do so. Our first option would be a two stage 7" liner cement job, however we are currently attempting to source necessary equipment to be able to purse it. If we are unable to perform a two stage 7" liner cement job, then we will top set our 7" liner at 10,900' MD, cement this new zone, and then drill a 6-1/8" hole section to planned TD of— 12,092' MD, and run and cement a 4- 1/2" liner as per the contingency liner option in the approved program, section 20. Both of these options will allow us to set our liner top at 6317' MD, above the leak in the 9-5/8" casing as per prior approval. I will let you know what option we will be pursuing once it is determined. As per our conversation, a sundry will be submitted. Thank you for your time. Please let me know if you have any questions. -Joe 2-66A L1IU WII Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 Number of Failures: 0 ✓ Test Results Test Time 3.5 Remarks: Test conducted with 5" test joint against TWC in hangar. Test time was not a full test. Electrical problems were encountered and the Top Drive co I t be lowered to test both kelt valves while I was on location. I did not witness the testing of either valve. Wi provide pictures of kelly valve(s) chart once received. STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.1. Supry � 11Z•'/0 ROPE Test Report for: DUCK IS UNIT MPI 2-66A Comm Contractor/Rig No.: Hilcorp Innovation PTDk: 2181060DATE: 9/17/2018 ' Inspector Austin McLeod - Insp Source Operator: HILCORP ALASKA LLC Operator Rep: Barber/Amend Rig Rep: Sweetsir/Unfreid Inspector Type Operation:. DRILL Sundry No: Test Pressures: Inspection No: bopSAM180917051707 Rams: Annular: Valves: MASP: Type Test: IN1T Quantity 250/4000 250/4000 ' 250/4000' 3496 Related Insp No: Size P/F TEST DATA Upper Kelly MISC. INSPECTIONS: NT �� Stripper MUD SYSTEM: ACCUMULATOR SYSTEM: NA P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P - P ' System Pressure 3000 - P Housekeeping: P_ Pit Level Indicators P - P Pressure After Closure 1550 - P " PTD On Location P Flow Indicator P P 200 PSI Attained 25 - P Standing Order Posted P _" Meth Gas Detector P P Full Pressure Attained 95 - P Well Sign P H2S Gas Detector P P Blind Switch Covers: All stations P Drl. Rig 1 MS Mise NA NA Nitgn. Bottles (avg): 6@2291 " P Hazard Sec. _P P 0 ACC Mise 0 NA Mise NA -2-7/811x5.5" P ' Number of Failures: 0 ✓ Test Results Test Time 3.5 Remarks: Test conducted with 5" test joint against TWC in hangar. Test time was not a full test. Electrical problems were encountered and the Top Drive co I t be lowered to test both kelt valves while I was on location. I did not witness the testing of either valve. Wi provide pictures of kelly valve(s) chart once received. BOP STACK: CHOKE MANIFOLD: FLOOR SAFTY VALVES: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly I NT �� Stripper 0 NA No. Valves 15 P ' Lower Kelly 1 NT Annular Preventer 1 13-5/8" P ( Manual Chokes 1 - P Ball Type I P• #1 Rams 1 '2-7/8"x5.5"P j Hydraulic Chokes 1 P Inside BOP 1 P #2 Rams 1 "Blinds P CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 -2-7/811x5.5" P ' 44 Rams 0 NA INSIDE REEL VALVES: #5 Rams 0 NA_ #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 -3-1/8" P Quantity P/F HCR Valves 2 '3-1/8" _ p Inside Reel Valves _ 0 NA Kill Line Valves 2 '21-1/8" P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 ✓ Test Results Test Time 3.5 Remarks: Test conducted with 5" test joint against TWC in hangar. Test time was not a full test. Electrical problems were encountered and the Top Drive co I t be lowered to test both kelt valves while I was on location. I did not witness the testing of either valve. Wi provide pictures of kelly valve(s) chart once received. 4�)6cc jA P' bg5p tM 116xr117051I 1107 �7 40 50 THE STATE °fALASKA GOVERNOR BILL WALKER Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-66A Hilcorp Alaska, LLC Permit to Drill Number: 218-106 Surface Location: 3152' FSL, 2360' FEL, SEC. 36, T12N, R16E, UM AK Bottomhole Location: 1340' FSL, 11 81'FEL, SEC. 35, T12N, R16E, UM, AK Dear Mr. Myers: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: Minimum LWD GR -Res required from KOP to T.D. 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, Hollis S. French Chair DATED this day of September, 2018. I STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 nr.%.4G1 V QLJ AUG 2 2 2013 A0GQQ 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas El Service - WAG L1 Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑v • Service- Winj ❑ Single Zane ❑Q Coalbed Gas ❑ Gas Hydrates ❑ Redrill Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q • Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 r DIU MPI 2-66A . 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive Suite 1400, Anchorage, AK 99503 MO: 12,093' • TVD: 10,233' Endicott Field Endicott Oil Pool ' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3152' FSL, 2360' FEL, Sec 36, T12N, R16E, UM, AK ADL034633 - Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Dale: 821' FSL, 874' FEL, Sec 35, T12N, R16E, UM, AK N/A 9/11/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1340' FSL, 1181' FEL, Sec 35, T12N, R16E, UM, AK 2560 3755'to nearest unit boundary 41b. Location of Well (State Base Plane Coordinates - NAD 27): ✓ 10. KB Elevation above MSL (ft): 39.8' • 15. Distance to Nearest Well Open Surface: x-258840. y- 5982293 . Zone -3 GL / BF Elevation above MSL (ft): 13.3' to Same Pool: 930' to END 2-52 16. Deviated wells: Kickoff depth: 7,500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 51 degrees Downhole: 4495 r Surface: 3496 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length J MD TVD MD TVD (including stage data) 8-1/2" 7" 26# L-80 DWC 4,743' 7,350' 5,828' 12,093'• 10,233' . 194.4 ft3 ✓ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 15,203' 11,501' 7,510' 7,510' 5,935' Casing Length Size Cement Volume MD TVD Conductor/Structural 94' 20" Driven 131' 131' Surface 2,829' 13-3/8" 950 sx 2,872' 2,739' Intermediate 10,011' 9-5/8" 10,056' 7,607' Intermediate 3,446' 9-5/81, 588 bbls 13,502' 10,075' Liner 2,005' 7" 158 bbls 15,200' 11,499' Perforation Depth MD (ft): Plugged w/ cmt Perforation Depth TVD (ft): Plugged w cmt Hydraulic Fracture planned? Yes El No P ' 20. Attachments: Property Plat O BOP Sketch Drilling Program e Time v. Depth Plot Shallow Hazard Analysis B e EL Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 6' 10 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'engel(Whilcorlp.com Authorized Title: Drilling Manager Contact Phone: 777-8395 Authorized Signature: Date: -------------Commission Use Only Permit to Drill API Number: ' Permit Approval See cover letter for other Number: a ($ — , Q 6 50- 3 �. Q I ^ Date: 7,0 1 b I requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methagas hydrates, or gas contained in shales: [l� Other: C30 V' C I QST �O /i 6©ODS t �ne, re, Samples req'd: Yes No Mud log req'd: Yes ❑ No['g-' E]L7 Ij 1 HzS measures: Yes [RO No ❑�Directional svy req'd: Yes [t]"No ❑ Q KSpacing r/ exception req'd: Yes No Inclination -only svy req'd: Yes ❑ No Cr ElL7 Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BYI I 1� Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and i� Form 10-401 Revised 512017 This permit is valid for 204 mo the from trideq a a C 25.005() n hments in Duplicate 7 IT H Hilmrp Alaska, LLC 8/22/2018 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 71h Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill Endicott MPI 2-66A Dear Commissioner, Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email jengel@hilcorp.com AUG 2 2 2018 AOGCC Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill a sidetrack production well at Endicott Main Production Island (MPI), well slot 2-66. Endicott MPI 2-66A is to be a slot recovery sidetrack producer with the Kekiktuk UPSZ (F -III, IV, and V) as the primary target. The parent well, 2-66, is a long term suspended well that was never produced (Suspended: 1993). The reservoir was abandoned and prepared for sidetrack with CTU in August 2018 (Sundry: 318-149). Current wellbore schematic is attached. Drilling operations are expected to commence approximately September 11, 2018, pending rig schedule. The Innovation Rig will be used to sidetrack and complete the wellbore. The existing 9-5/8" surface casing will be used and a pressure test conducted prior to drilling the sidetrack. A clean out run will be performed, a whip stock assembly will be run and set, and a window will be milled at ±7,500' MD / 5,930' TVD. The directional plan for this sidetrack will be to drop to a 160 inclination and held to TD, 8-1/2" hole will be drilled to ± 12,093 MD / 10,233' TVD. 7" liner will then be run and cemented, the 7" liner top packer will be set at depth sufficient to cover the casing leak identified in the 2-66 reservoir abandonment (Sundry #318-149). The well completed with a 3-1/2" gas lift completion. Post rig evaluation and perforation will follow. Please find attached the Form 10-401, Application For Permit to Drill per 20 AAC 25.005 (a), and the drilling program for Endicott MP 2-66A, which includes information required by 20 AAC 25.005 (c). If you have any questions, or require further information, please do not hesitate to contact myself (Joe Engel) at 777-8395 or jengel@hilcorp.com or Monty Myers at 777-8431 or mmyers@hilcorp.com. Sincerely, Engel Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC Endicott MPI 2-66A Sidetrack Drilling Program Version 1 August 22, 2018 END 2-66A Sidetrack 0 1 Drilling Procedure nil.rp Alk., LLC 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 Casing Inspection............................................................................................................................4 6.0 Internal Reporting Requirements..................................................................................................5 7.0 Current Wellbore Schematic..........................................................................................................6 8.0 Proposed Wellbore Schematic........................................................................................................7 9.0 Drilling / Completion Summary.....................................................................................................8 10.0 Mandatory Regulatory Compliance / Notifications.....................................................................9 11.0 Rig Orientation on Endicott MPI: ............................................................................................... 11 12.0 Reservoir Abandonment & Sidetrack Preparation....................................................................12 13.0 Milling & Drilling Fluid Program................................................................................................13 ' 14.0 Cleanout Run, MU and RIB with 9-5/8" Whipstock Assembly................................................15 15.0 Set Whipstock and Mill 9-5/8" Window......................................................................................18 16.0 Drill 8-1/2" Hole Section...............................................................................................................20 17.0 Run 7" Liner..................................................................................................................................23 18.0 Cement 7" Liner............................................................................................................................26 19.0 Perform 7" Cleanout Run & 7" CBL..........................................................................................28 20.0 Contingency 6-1/8" OH x 4-1/2" Liner........................................................................................29 21.0 Run 3-1/2" Upper Completion.....................................................................................................30 22.0 RDMO............................................................................................................................................32 23.0 Innovation Rig BOP Schematic....................................................................................................33 24.0 Days vs Depth.................................................................................................................................34 25.0 Formation Tops & Information...................................................................................................35 26.0 Anticipated Drilling Hazards.......................................................................................................38 27.0 Innovation Rig Layout..................................................................................................................39 28.0 FIT Procedure................................................................................................................................40 29.0 Innovation Choke Manifold Schematic.......................................................................................41 30.0 Casing Design Information...........................................................................................................42 31.0 8-1/2" Hole Section MASP............................................................................................................43 32.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................44 33.0 Surface Plat (As Built) (NAD 27).................................................................................................45 34.0 Drill Pipe Information 5" 19.5# 5-135 DS -50 & NC50...............................................................46 U Ilil.q Alaska, LLC 1.0 Well Summary END 2-66A Sidetrack Drilling Procedure Well 2-66A Pad Endicott MPI Planned Completion Type 7" Cemented Liner / 4-1/2" Gas Lift Target Reservoir(s) Kekiktuk UPSZ (F -III, IV, V) Planned Well TD, MD / TVD 12,093' MD / 10,233' TVD PBTD, MD / TVD (12,000' MD / 10,144 TVD Surface Location (Governmental) 3152' FSL, 2360' FEL, Sec 36, T12N, R16E, UM, AK Surface Location (NAD 27 — Zone 4) X=258,840.95 Y=5,982,293.3 Top of Productive Horizon (Governmental) 821' FSL, 874' FEL, Sec 35, T12N, R16E, UM, AK TPH Location (NAD 27) X= 254975.03, Y= 5980086.45 BHL (Governmental) 1340' FSL, 1181' FEL, Sec 35, T12N, R16E, UM, AK BHL (NAD 27) X=254684.45, Y=5980615.03 AFE Number 1811485 AFE Drilling Das 14 AFE Completion Days 6 AFE Drilling Amount $2,498,073 AFE Completion Amount $2,036,261 AFE Facility Amount $450,000 Maximum Anticipated Pressure (Surface) 3,496 psig Maximum Anticipated Pressure (Downhole/Reservoir) 4,495 psig Work String 5" 19.5# NC50 & DS50 KB Elevation above MSL: 26.5 + 13.3 ft = 39.8 ft AMSL GL Elevation above MSL: 13.3 ft AMSL BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 August 2018 H Inl,.q, U.A.. LLL: 2.0 Management of Change Information END 2-66A Sidetrack Drilling Procedure 11 Hileorp Alaska, LLC E iC Changes to Approved Permit to Drill Date: 8/21118 Subject: Changes to Approved Permit to Drill for Endicott MPI 2-66A File #: Endicott MPI 2-66A Drilling and Completion Program Any modifications to Endicott MPI 2-66A Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the AOGCC. Approval: Drilling Manager Prepared: Drilling Engineer Page 3 Date Date August 2018 By U nil ... p AI.A., LLC 3.0 Tubular Program: END 2-66A Sidetrack Drilling Procedure Hole Section OD (in) H) (in) Drift in Conn OD in Wt (#/ft(psi)(psi) Grade Conn Burst Collapse Tension (k -lbs) 8-1/2" 7' 6.276 6.151 7.875 26 1-80 DWC/C 7240 5410 604 4.0 Drill Pipe Information: 5.0 Casing Inspection All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 August 2018 H llilmrp Alaska. LIX 6.0 Internal Reporting Requirements END 2-66A Sidetrack Drilling Procedure 6.1 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. 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. 6.2 Detailed Daily Plan Forwards • Distributed to ieneelna hilcop.com and mmyers@hilcol2.com 6.3 Afternoon Updates • Submit a short operations update each work day to pmazzolini(c�r�hilcorp.com, mm, ers e.hilcorp.com, ieneel@hilcorp.com and cdinizer@hilco[P.com 6.4 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 6.5 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drilling Manager & Drilling Engineer • Submit Hilcorp Incident report to contacts above within 24 hrs 6.6 Casing Tally • Send final "As -Rud' Casing tally to mmyers[a hilcorp.com, iengel@hilcorp.com and cd inger(c�hilcoW.com 6.7 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers a hilcorp.com, iengel@hilcorp.com and cdineerna hilcorp.com 6.8 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyersCc@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 jengd@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.943.9533 twellman@hilcorp.com Geologist Daniel Yancey 907.748.8458 907.250.9632 dvancevC@hilcorp.com Reservoir Engineer Chris Kanyer 907.777.8377 907.250.0374 ckanver@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 907.350.9439 kflemin¢@hilcoro.com EHS Manager Carl Jones 1 907.777.8327 907.382.4336 1 caiones@hilcorp.com Drilling Tech Cody Dinger 1 907.777.8389 1 509.768.8196 1 cdin¢er@hilcorp.com Page 5 August 2018 K Hit uoep Alaakar LLC 7.0 Current Wellbore Schematic nSCHEMATIC IIIM1..n AL.-A..I I,i v END 2-66A Sidetrack Drilling Procedure Duck Island Unit Well: END 2-66 Last Completed: 10/2/1993 PTD: 193-079 IB9ee.57/�DM;15• SAFETY NOTES TREE&WELLHEAD 1 DW15 125 Readn�Avmae 230-260 PPM on AA&WSIMadan Tree TULIP Wdl Re4uiraa555v I Wdihead I cm OPEN MOLE /CEMENT DETAIL 13.31•Staae: 550 328CNssE/N'Sbae:400 IS.Bp doss E§�16'Hde 95/8" la5tye:'A)bbb, S2N doss G/2"'$qe: 8l bbls, ]5.8tl CIessGin l2-U4'flde er+axi� P.Iw9Mlw ,33V pma6y Ve • ._._..._....._...-._--------------- CASING DETAIL ------- .....___. No Depth .- ' Size Type I WI/Grade/Conn ID Top Bbn I BPI 20" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-0368/1+801M 12415 Surfaee 2,872' 0.1497 95/8" Pmdudion 47/N1R0S/NSCC 9,01 Surfs. 10,056' 0.0732 95/8" Production 47/NT95HS/NX 8681 101056' 13,50T 0.0)92 )" finer 126/IMr80/NSC[ 6.184 13,195' 15,2W 0.0372 TUBING DETAIL 4- Tud L-80 1 3.958 1 Surface 1 3' 10.0152 UX S1.tm n4 toad T.m IEWELRV DETAIL No Depth Rem 1 8,000 951rcleP 2 13,195' Ba T Badr5l. 3 13,203' 95/MZT BaIerType'H' w/Ffa Lad Rrrr Maryer a Tsane.1 t9,a,2 a r ;ji�ihh)it'SYV TD=3sxB' INS ITD= 21sor)rvDl PBm =2slrr PBq / PBID=11p8D-p W) WELL INCLINATION DETAIL KOP @500' Mss Hpk Male=S) PERFORATION DETAIL I END Sands I Top IMO) I Btm IMD) I Top ITVDI I Btm (WD) I FT I Date I Status I size I INFO Revered B,'. UW 8/10/2018 Page 6 August 2018 H Ililoorp Alaska, I.LC 8.0 Proposed Wellbore Schematic nPROPOSED SCHEMATIC Id:,vu.ux.Lu. IA i / r To=11,W(MDI/1D=1(1233'fTWD) P9TD=12,D10 (MD) / PBTD=10u"(M) END 2-66A Sidetrack Drilling Procedure Duck Island Unit Well: END 2-66A Last Completed: xx/xx/xxxx PTD: TBD SAFETY NOTES TREE & WELLHEAD H2SReadings AvmV2M-2WPPMon A/L&Gaslnjectors Trce 41/16"CIW Well Requires a SS5V WNihead CIW OPEN HOLE /CEMENT DETAIL 13-3/8' 1 4,557 Vft Permafrost in 1].s' Nae 9-5/8" 575 Claz W in a 11-1/4' Hoe r 194 Class'G-In&U2"Hole — - --------------------------------------------------------------------------- CASING DETAIL Btm (MD) Top (ND) Btm (TVD) FT Date Status Size um Sim Type I Wt Grade/Conn I Drift ID Top Btm BPF 20" Conductor N/A/N/A/N/A N/A Surface N/A 13-3/a' sarWe 58/1-eo/ U415 wdaoe 2,B]z G. A 9-5/r Production 47/NT80S/NSCC &S81 Surface 47,SW 0.0]32 ]" U. 2fi/L-80/DWC 6.184 ],330' 12,093' 0.0372 TUBING DETAIL 3-2/2- Tubi 9.3 1301 SFE Bear 1 2.932 1 Surface I ±11 .600 0.008] WELL INCLINATION DETAIL M.a Nok Mme=40 deg. @8.294' Mgkat Tap Pert=36 Da IS 10,798' , 4o&Vaf7?4-%1 &41116 PERFORATION DETAIL END Sands Top (MD) Btm (MD) Top (ND) Btm (TVD) FT Date Status Size um TBD Refmrc LOW GENERAL WELL INFO MI: 5"29 -22374 -0D -M Initial Completion -10 1983 Page 7 August 2018 H Ifilmrp Alaska, LLC 9.0 Drilling / Completion Summary END 2-66A Sidetrack Drilling Procedure Endicott MPI 2-66A is to be a slot recovery sidetrack producer with the Kekiktuk UPSZ (F -III, IV, and V) as the primary target. The parent well, 2-66, is a long term suspended well that was never produced (Suspended: 1993). The reservoir was abandoned and prepared for sidetrack with CTU in August 2018 (Sundry: 318-149). Current wellbore schematic is attached. Drilling operations are expected to commence approximately September 11, 2018, pending rig schedule The Innovation Rig will be used to sidetrack and complete the wellbore. The existing 9-5/8" surface casing will be used and a pressure test conducted prior to drilling the sidetrack. A clean out run will be performed, a whip stock assembly will be run and set, and a window will be milled at ±7,500' MD / 5,930' TVD. The directional plan for this sidetrack will be to drop to a 160 inclination and held to TD, 8-1/2" hole will be drilled to ± 12,093 MD / 10,233' TVD. 7" liner will then be run and cemented, the 7" liner top packer will be set at depth sufficient to cover the casing leak identified in the 2-66 reservoir abandonment (Sundry #318-149). The well completed with a 3-1/2" gas lift completion. Post rig evaluation and perforation will follow. All waste & mud generated during drilling operations will be hauled to the Milne Point G&1 facility on `B" pad. A separate sundry notice has been submitted to cover reservoir abandonment and wellbore preparation for the sidetrack. The aforementioned sundry will cover the following operations: 1. MIRU E -Line & ASR and abandon reservoir and prep for sidetrack. RDMO 2. MIRU the Innovation Rig. Test BOPE 3. RIH w/ 9-5/8" cleanout assembly to top of cement plug +/- 7,500 MD 4. RH-I w/ whipstock and set on top of cement 5. Mill window at +/- 7,500' MD General sequence of operations pertaining to this approved drilling procedure: 1. Kick off and drill 8-1/2" production hole section to TD 2. Run 7" and cement 3. Run 3-1/2" Completion 4. N/D BOP, N/U tree, RDMO Page 8 August 2018 H nik.rp AI.A., I.I.0 END 2-66A Sidetrack Drilling Procedure 10.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with all 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 2-66A. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure both AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: • There are no variance requests at this time. Page 9 August 2018 N 11H.rp Alaska, LIA: Summary of BOP Equipment and Test Requirements END 2-66A Sidetrack Drilling Procedure Hole Section Equipment Test Pressure si • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/4000 o Blind ram in bottom cavity (Annular 2500 psi) • Mud cross w/ 3" x 5M side outlets 8-1/2" OH x 7" • 13-5/8" x 5M Control Technology Single ram Casing 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/4000 • 3-1/8" x 5M Choke manifold (Annular 2500 psi) • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen The remote closing operator panels are located in the doghouse and on accumulator unit. 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. Additional requirements may be stipulated on APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regagalaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz(c>7.alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectorst7a alaska.gov Test/Inspection notification standardization format: ho://doa alaska.gov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 August 2018 H Ililrvmp kI.A.. LLC 11.0 Rig Orientation on Endicott MPI: END 2-66A Sidetrack Drilling Procedure Page 11 August 2018 ■ 2-36 ■ 2-38 ■ 2-40 ■ 2-42 2-44 2-46 ■ 2-62 ■ 2-48 2-64 ■ 2-50 -66 ■ 2-52 ■ 2-54 2-68 2-56 ■ 2-70 2-58 ■ 2-62 2-64 666 2-68 ■ 2-70 Endicott MPI 'Drawing Not To Scale Page 11 August 2018 H Ilil.rp Ala ku, LLC END 2-66A Sidetrack Drilling Procedure 12.0 Reservoir Abandonment & Sidetrack Preparation 12.1 Reservoir abandonment was completed pre rig by CTU. A separate sundry was submitted and approved by the AOGCC (Sundry 4318-149). A summary of sundry operations is below: MIRU CTU, Set IBP Retainer & Spot 500' Cement & RDMO A 9-5/8" casing leak was identified during the pre -rig reservoir abandonment. The 7" liner top packer will be set at depth sufficient to cover the casing leak. 12.2 Level pad and layout rig mats for footprint of rig. 12.3 MIRU Innovation over well and ensure rotary centered over wellhead. Confirm that rig is over appropriate well — 2-66. 12.4 Spot & tie in service company shacks and water/displacement tanks. 12.5 Ensure Sundry, PTD and drilling program are posted in the rig office and on the rig floor. 12.6 Mud loggers will not be used on this well. 12.7 Keep 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. 12.8 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. / 12.9 ND tree, NU BOPE and test fe Y&V6/QS/ . V B 400 �e47�ev Zoo S /�e5 • 5" Test Joint lar f es 1t �iO "'O O /10 12.10 Pull & Lay Down 4-1/2" Tubing pup, 3' Length 12.11 PU RTTS, RIH and Test 9-5/8"integrity above planned 7" liner top. Chart Test — • Depth: ±7,350' MD • Test Pressure & Duration: 2500 psi / 30 min • This test will be used to confirm 7" liner top packer depth will isolate 9-5/8" casing leak found during CTU reservoir abandonment of 2-66. • If unable to get a passing test, consult Operations Engineer. Plan will be to pull up hole and determine new liner top set depth. 12.12 Sidetrack preparation operations were by E -line & ASR. A separate sundry was submitted and approved by the AOGCC (Sundry #318-149). A summary of sundry operations is below: MIRU CTU, Set IBP Retainer & Spot 500' Cement & RDMO Page 12 August 2018 H nilmrp Alaska, I.I.0 END 2-66A Sidetrack Drilling Procedure 13.0 Milling & Drilling Fluid Program • Fluid Type: 9.5 - 10.3 ppg 3% KCl Gem GP LSND Fluid Density: C•] MD, ft Density, ppg 7, 500 - 10565 0,565 - TD 9.5 10.3 Total Solids MBT HPHT iiO itili After TD 10.3 - 10.8* Maintain 9.5 ppg until --500' above HRZ. Increase MW to 10.3, using pre sheared balanced spike fluid for hole stability while drilling to TD. Pending hole stability, MW may be increased at TD up to 10.8 ppg. Mud weights chosen based upon pore pressures and hole stability pressures while drilling through unstable formations. 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. Rheology: o Milling Fluid: Maintain YP 40-60 for metal cuttings removal o Drilling Fluid: Maintain YP between 14 - 21, 6 RPM/Tau reading of 1.0 - 1.2 x the hole diameter to optimize hole cleaning. Other: o Stabilize the HRZ shale formation with the use of mud weight and adequate concentrations of shale stabilizers (GEM, BAROTROL PLUS, Soltex and BDF-515). o Increase the KCl concentration from 3% to 6% and add BARASURE-499 at 4 ppb if heavy clays are encountered to increase inhibition of the native clays Solids Control: o Run shakers with as fine a screen as possible Size shakers screens with coarse mesh initially. Adjust screen size as solids loading, mud rheology and flowrates allow. • Inspect the shakers frequently, taking time to repair/replace damaged screens. • 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. o Run the centrifuge continuously while drilling this hole section, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. o Dump and dilute as necessary to keep drilled solids to a minimum o Optimize solids control equipment to maintain density, ECD and minimize LGS Prnnortiae- Depths DensityPlastic ViscosityYield Point Total Solids MBT HPHT H 7,500'- 12,093' 9.5-10.3 15-25 14-18 <6% <20 <11.0 9-10 Page 13 August 2018 0 Hilw,p Alaska, IIA: S stem Formulation: END 2-66A Sidetrack Drilling Procedure Product Mill Out to Top of HRZ Top of HRZ to TD Concentration Concentration Water 0.94 bbl 0.94 bbls KCL 11 ppb 11 ppb Caustic soda 0.2 ppb 0.2 ppb BARAZAN D PLUS 1.25 ppb (as required for 14 - 18 YP) 1.25 ppb (as required for 14 —18 YP) N-DRIL HT 3.0 ppb 4.0 ppb GEM GP 0 % v/v 2 % v/v BARACARB 5 2.5 ppb 4 ppb BARACARB 50 2.5 ppb 4 ppb BARACARB 150 0 ppb 12 ppb BAROTROL PLUSBDF-515 4.0 ppb (2 ppb each) 8 ppb (4 ppb each) BARASURE - 499 2-4 ppb (if heavy clays are encountered) 2-4 ppb (if heavy clays are encountered) BAROID 41 as required for a 9.5 ppg MW as required for 10.4 — 10.8 ppg BARACOR 700 1.0 ppb 1.0 ppb BARASCAV D 0.5 ppb 0.5 ppb ALDACIDE G 0.25 ppb 0.25 ppb Page 14 August 2018 K nifmrp M.A., IAA: END 2-66A Sidetrack Drilling Procedure 14.0 Cleanout Run, MU and RIH with 9-5/8" Whipstock Assembly 14.1 MU 9-5/8" Cleanout BHA 14.2 Perform cleanout run • RIH on 5" DP to — 7,510' MD, tag top of cement and displace wellbore to 9.5 ppg LSND milling fluid • Confirm with casine tally, CCL loe and tae depth placement log to ensure whisptock and window will not be across a collar, if necessary, drill cement to ensure proper whipstock placement • CBU & circ at least (1) hi -vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. • Obtain PU/SO and ROT, document. This will be used to set up shear pins and bolt for whipstock and anchor • POOH, ensure no changes to DP tally after cleanout run. • This is to prevent tagging up early and inadvertently setting the anchor 14.3 M/U window milling assembly as per Baker BHA tally • The milling BHA will consist of: 0 8.5" Window Mill 0 8.25" Lower Mill 8.5" Upper Mill • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. Ensure there is an extra set of mills on location in the event that the upper mills come back under gauge and a dress off run is required. 14.4 PU remaining components of milling/whipstock BHA • Make up HWDP, 2-3 String Magnets, and float sub • Ensure magnets are in the trough under the shakers and flow area Page 15 August 2018 n Hileerp Alaska, LIX END 2-66A Sidetrack Drilling Procedure WindowMaster G2 BHA BHAComponent Approx. Length OD Bottom Trip Anchor 3 8.375 Window Master G2 Whipstock 18.5 8 Window Mill 1.6 8.5 Lower Watermelon Mill 5.7 8.25 Flex Joint 9 5 Upper Mill 6.3 8.5 HWDP 30 5 MWD Collar 18 6.75 Float Sub 3 5 UBHO 4 5 XO 4 5 HWDP 30 5 String Magnets 5 ..r ao B quGHES a+r D -r- Gen II Whipstock loo ' Cue:o.el. Hilcon, •X weir i Ull will Rq i tnnuvabon I xfr .wr[Q I.w a w D T— a.r .n. w •w Fill J" 211W 00 Wkir.f..k tAN ear a0 •wD fM loo nrr s— r W L..wrnlll SIT 3r _ T e a•tt 81r'OO 1 T-1 aax•oo r.r o .sr ct 2r au.•00 �r - wMrsw to -L tar Page 16 August 2018 H Ilii. q Al.ku. LLC END 2-66A Sidetrack Drilling Procedure 14.5 Install MWD and UBHO, and orient. Rack back mill assembly. • Ensure a dedicated MWD is available for orientation of the whipstock 14.6 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed, based upon previous down hole parameters and any safety screws. • A pup joint below the anchor maybe needed to set anchor on cement plug Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. Pending PU/SO on cleanout run, REMOVE 2-3 screws for a set down shear of 6,630 x 3 =19,890 lbs. Note: Attach mills to Whipstock with (1) 35k mill shear bolt (45k bolt will be available if necessary) 14.7 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover 14.8 Release pick up system at this point, Make up mills. 14.9 With the top drive, pick the mill assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up, the shear bolt then can be made up by the Baker Rep. 14.10 The assembly can now be picked up to ensure that the shear bolt is tight. 14.11 Remove the handling system. 14.12 Verify offset between MWD and Whipstock tray, witnessed by Drilling Supervisor, MWD and Baker Rep. Document and record in well file. 14.13 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing to prevent damaging the shear bolt. 14.14 Run in hole at 1 %2 to 2 minutes per stand. Ensure work string is stationary prior to setting the slips, and removed slowly as well. These precautions are to avoid weakening the shear bolt and prematurely setting the anchor. 01.11l�iUMAD 14.15 Fill every 30 stands or as needed, do not rotate or work the string. 14.16 Call for Baker Rep. 15 — 10 stands before setting depth 14.17 Stop at least 30'-45' above the tagged cement, obtain survey using the MWD. Consider having gyro personnel on standby in the event the MWD is not working. Page 17 August 2018 n 1101 ,p Al.ka, LIA: 15.0 Set Whipstock and Mill 9-5/8" Window END 2-66A Sidetrack Drilling Procedure 15.1 With the bottom of the Whipstock 30 — 45' above the cement base, work torque out of string, measure and record P/U and S/O weights. Obtain good survey to orient Whipstock face. 15.2 Orient Whipstock to desired direction by turning DP in'/4 round increments. P/U and S/O on DP to work all torque out after oriented. (Being careful not to set trip anchor). Target orientation is 30° ROHS, due to side track directional targeting down and right. Whipstock Orientation Diagram: 45R Desired orientation of the Whipstock face is 15R to 45R, target is 300 ROHS Hole Angle at window interval (7,500 MD) is —46 deg. 15.3 Once Whipstock is in desired orientation, slack off and tag anchor to set Bottom Trip Anchor. 15.4 Set down 15-20K on anchor (based upon number of shear pins) to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (35k shear value, verify after whipstock is picked up). 15.5 P/U 5-10' above top of Whipstock. 15.6 CBU and confirm 9.5 ppg MW in/out ' • Ensure Mud properties are sufficient for transporting metal cuttings • Vise: 40-60, YP: 18-20 15.7 Record P/U, S/O weights, and free rotation. Slack off to top of Whipstock and with light weight and low torque. Mill window as per Baker Rep. Utilize 4 ditch magnets on the surface to catch metal cuttings. Pump high vise sweeps as necessary. 15.8 If possible, install catch trays in shaker underflow chute to help catch metal cuttings. 15.9 Clean catch trays and ditch magnets frequently while milling window Page 18 August 2018 K 11&4 p M.A.. LLC END 2-66A Sidetrack Drilling Procedure 15.10 Mill window until the uppermost mill has passed across the entire tray. Dress and polish window as needed. With upper mill at the end of the tray, this will drill — 20' of new hole. 15.11 Estimated metal cuttings volume from cutting window: 9-5/8" 47# NT80 Cuttings Weight Window Tray Length Casing Weight Min (lbs) Avg (Ibs) Max (lbs) 17 47# 120 160 240 15.12 After window is milled and before POOH, shut down pumps and work milling assembly through window watching for drag. Dress and polish window as needed. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 15.13 Circulate Bottoms Up until even MW in/out and hole is clean of metal shavings. Reduce mud properties for drilling. d e/ J / J �yC '�� ��/ F/GLC �O .�✓dwC �p 15.14 Pull back into 9-5/8" casing and perform FIT t/ 12.5 ppg EMW./Chart T st. 15.15 POOH & LD Milling BHA. Gauge Mills for wear. 15.16 If upper mill is under gauge, pick up second mill BHA with same assembly (to ensure same cut pattern) and perform dress off run to ensure window is correct diameter. 15.17 PU stack washer and wash BOPE stack. Function all rams to clear any potential milling debris. Page 19 August 2018 0 llil.o p AI.A., L1.0 16.0 Drill 8-1/2" Hole Section END 2-66A Sidetrack Drilling Procedure 16.1 Pick up 8.5" Motor BHA • Motor BHA will be used ensure kick off and drill enough full gauge OH for the RSS BHA IT ,_L.�T +1 Confirm that Tool Face Offset has been correctly recorded • Tracked parent casing, difficulty ensuring kick off and TT have been caused to to incorrect TFO 16.2 RIH with Motor BHA t/ 3 stands above whipstock 16.3 CBU to ensure even MW in/out and mud properties are back to desired for drilling • Double check tally's to make sure bit is well above whipstock to prevent rotating bit tagging whipstock 16.4 Orient motor and continue lowering assembly through window with no flow or rotation • Ensure BHA and DP tally are verified • Circulating can cause the rotating bit to catch the whipstock and result in rotating it or becoming mechanically stuck 16.5 Once through the window and tagged up on bottom, drill ahead to confirm kick off, build to tangent angle and ensure clearance for RSS BHA. 16.6 Orient motor and pull through the window with no flow or rotary I-rf � IGNTI MIRAD AIRISaUN3 16.8 P/U 8-1/2" RSS 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. • Workstring will be 5" 19.5# S-123 NC50 • Ensure float is ported 16.9 TIH w/ 8-1/2" directional assembly to 2-3 stands above window. Shallow test MWD and LWD �• on trip in. 16.10 Trip through window with no flow or rotation, to bottom 16.11 Drill 8-1/2" hole section to section TD, — 12,093 MD, as per Geologist and Drilling Engineer. Page 20 August 2018 R 11R.,p Ala ku, LIA: END 2-66A Sidetrack Drilling Procedure • Flow Rate: 400-550 gpm (Target is 200 ft/min AV for hole cleaning) • RPM: 120+ • WOB: 10-30 klb • Adjust RPM and WOB as needed • 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 tandem high weight high visc / low weight low visc sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Take MWD surveys every stand drilled • 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. • Endicott Formation Descriptions are attached to this program. This well will encounter Itkvliark, high compressive strength limestone with notorious hard drilling. Monitor bit performance through the Itk and after. A bit trip may be need and is planned for in the AFE • Monitor Drag, Torque and ECD Curves for indication of hole cleaning. Circulate at full flow and full rpm if necessary • Maintain ECD maximum of 1 ppg over static MW after drilling in to HRZ to minimize pressure cycles on formations • Monitor breakover torque and PUW on connections for differential sticking risk. • Perform short trips as needed. CBU x 2 before each short trip to clear BHA and cuttings from the open hole • Past interval of — 2000' MD drilled have proven beneficial in past Endicott wells 16.12 8-1/2" Section Mud Weights: MD, ft Density, ppg 71500- 10565 9.5 565 - TD 10.3 Afte r TD 10.3 - 10.8' Window — 500' MD Above HRZ (10,565 MD): 9.5 ppg 500' MD Above HRZ — TD: 10.3 ppg, increase inhibition, GEM and black products Baratrol and Baranex nsnrnaieu pure pressure is — 6.3 ppg. 3rauc rvi w necessary 101 snare sraourry Is ru..I ppg. This is 2 ppg difference. Ensure mud properties are sufficient to provide good filter cake. Keep pipe moving at all times. Uppermost Kekiktuk Sand: 11840' MD - 16.13 At TD, Circulate 5-6 BU at maximum circulation and rotation, pump tandem sweeps as needed. Alternate reciprocation depths while CBU to reduce risk of troughing and dropping inclination • Flow Rate: 400 gpm, Minimum • RPM: 120 Page 21 August 2018 / U ffil.q Alaska, LLC 16.14 After CBU's, Perform a short trip to above the HRZ This will give an indication of hole quality & hole stability 16.15 CBU and TIH to Bottom 16.16 If hole condition indicates, weight up mud system, 10.8 ppg max END 2-66A Sidetrack Drilling Procedure 16.17 Spot liner running pill at TD t/ above HRZ • MW at TD will be based upon and differential sticking risk and hole condition seen at 10.3 ppg. MW may need to be cut once on bottom with liner due to cementing ECDs. Confirm MW at TD with Drilling Engineer. 16.18 POOH to -- 2 stands below window Minimize surge/swab pressures String speed 500 fph t/ above HRZ, Increase as hole conditions allow above HRZ. Max pulling speed 2000 ft/min Watch overpulls, if any overpull over 25k1b is encountered, RIH 2 stands and CBU 16.19 CBU x 2 below window, 400 gpm, 120 rpm 16.20 Pull through window with no pumps or rotation 16.21 If backreaming is necessary: • CBU x 2 before beginning backreaming operations, this is to clear the BHA of cuttings and reduce packoff risk • Circulate at max rate, matching ECD's seen while drilling • 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 2 stands below window • CBU x2 outside of window • Pull through the window with no pumps or rotation. 16.22 TOH with the drilling assembly, racking back DP, Rabbit DP on TOH at the window for liner run • Do not lay down drill pipe or soft break connections while TOOH. Drill pipe will be handled after 7" liner is landed and cemented 16.23 Lay Down BHA • 16.24 No additional logs are planned for the 8-1/2" hole section. Page 22 August 2018 H Itil... p AIuA., LIA: 17.0 Run 7" Liner 17.1 Change upper pipe rams to 7" solids and test with 7" test joint. 17.2 Ensure wear bushing is installed in wellhead. END 2-66A Sidetrack Drilling Procedure 17.3 R/U 7" casing running equipment. • Ensure 7" x NC50 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. 17.4 Run 7" 26# L-80 DWC/C liner per completion tally • Use "API Modified" or "BOL 4010 NM" thread compound. Dope pin end only w/ paintbrush. • Utilize a collar clamp until weight is sufficient to keep slips set properly.. • 7" Shoe track will consist of: I Landing Collar I 2 its Float Collar 1 it • Run Centralizers as per below, until — 1000' MD above shoe • Centek SII 7" x 8.5" Bowsprings Depths Centralizer Frequency TD — 11540' 2 per 1 Joint (stop ring in middle) 11540'— 11000' MD 1 per 1 Joint • Slow running liner across whipstock to ensure centralizers do not catch • Fill liner every 10-20 joints, more frequently if needed 7" Tenaris DWC/C M/IJ Torques Casin OD Minimum Maximum Yield To ue 7" 18,300ft-lbs 2 1, 100 ft-Ibs 23,800 ft -lbs *7" DWC/C is compatible with TXP & BTC Page 23 August 2018 Technical Specifications Connection Type: Slze(O.D.): DWCfC Casing 7 in 2012 API SPEC 5CT COUPLING O.D. API Joint Strength (lbs.) Material L-80 Grade 80,000 Minimum Yield Strength (psi.) 95,000 Minimum Ultimate Strength (psi.) Maximum Uniaxial Bend Rating [degrees]100 ft] Pipe Dimensions 7.000 Nominal Pipe Body O_D_ (in.) 6.276 Nominal Pipe Body I.D. (in.) 0.362 Nominal Wall Thickness (in.) 26.00 Nominal Weight Obs./ft.) 25.69 Plain End Weight (Ibs.ft) 7.549 Nominal Pipe Body Area (sq_ in.) Pipe Body Performance Properties 604,000 Minimum Pipe Body Yeid Strength (lbs.) 5,410 Minimum Collapse Pressure (psi.) 7,240 Minimum Internal Yield Pressure (psi.) 6,600 Hydrostatic Test Pressure (psi.) Connection Dimensions 7.875 Connection O_D_ (in.) 6.276 Connection I.D. (in.) 6.151 Connection Drift Diameter (in.) 4.50 Make-up Loss (in.) 7.549 Critical Area (sq. in.) 100.0 Joint Efficiency (%) Connection Performance Properties END 2-66A Sidetrack Drilling Procedure Weight (Wall): Grade: 26.00 Iblft (0.362 in) L-80 604,000 Joint Strength (lbs.) 16,590 Reference String Length (ft) 1.4 Design Factor 641,000 API Joint Strength (lbs.) 302,OD0 Compression Rating (lbs) 5,410 API Collapse Pressure Rating (psi.) 7,240 API Internal Pressure Resistance (psi.) 26.2 Maximum Uniaxial Bend Rating [degrees]100 ft] Approximated Field End Torque Values 18,300 Minimum Final Torque (ftAbs.) 21,100 Maximum Final Torque (ft.4bs.) 23,800 Connection Yield Torque (ft. bs.) -USA VAM USA 4424 W. Sam Houston Pkwy. Sude 150 Houston, TX 77041 Phone: 713-479-3200 Fa)c 713-479-3234 E-mail: VAMUSAsaL—�vam-um.00m 0 For detailed information on perfomsance propertks, refer to DWC Connection Data Notes on following page(s)- Page 24 August 2018 H Ilil.q Awake, IAX END 2-66A Sidetrack Drilling Procedure 17.5 Ensure to run enough liner to provide for — 150' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. • Ensure 7" liner top packer set depth is consistent with test packer depth determined at the beginning of the well. The 7" packer will isolate a 9-5/8" casing leak found during the pre- rif4 CTU reservoir abandonment of 2-66. 17.6 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. 17.7 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. 17.8 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 17.9 RIH w/ liner on DP no faster than 1-1/2 min / stand. Watch displacement carefully and avoid surging the hole and catching liner on whipstock. Slow down running speed if necessary. 17.10 Fill DP every 5 stands, or more frequently if needed 17.11 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. 17.12 Obtain up and down weights of the liner before RIH. Record rotating torque at 10, 20, & 30 rpm. Liner will be ran through historically troublesome formations. Rotation of the liner may be necessary. If rotation and circulation is required, ensure to say well below torque and pressure limits, dictated by liner spec sheet and Baker hanger/setting tool pressures. Break circulation slowly and limit reciprocation speeds to limit surge and swab pressures 17.13 RIH t/ planned setting depth of±12,093' MD. • Limit running speeds to reduce pressure cycles on shales • CBU every 2000' MD while RIH • Monitor drag while RIH, stop and circulate BU as needed • Differential sticking has been seen across the Kekiktuk. Minimize the time the pipe is left station while running through this interval. Estimated pore pressure is 8.3 ppg, and MW for shale stability is 10.3 ppg minimum. • At depth, double check all drill pipe and liner tallies. Ensure all numbers agree with final depth • If unable to get 7" liner to TD, liner will be set high and cemented and lowest achievable depth. A 6-1/8" cleanout run will be performed and an 4-1/2" contingency liner ran. Page 25 August 2018 U mp•mp M.A., LIA: 18.0 Cement 7" Liner 18.1 Circulate and condition mud for cement job END 2-66A Sidetrack Drilling Procedure Break circulation slowly and stage up rate with reciprocation. Rotate DP slowly if hole condition allows, not exceed max liner torque or 20 rpms Circulate minimum 3 liner annular volumes to condition hole and mud for cement job Max flow rate 5-7 bpm, ensure to not exceed drilling ECDs or --11.5 ppg EMW, estimated fracture gradient of Kekiktuk 18.2 Hold pre job safety meeting over upcoming liner cementing operations. Make room in pits for volume gained during cement job. Ensure adequate displacement volume is available. • Cement returns are not expected to surface, but may be seen after setting liner hanger and circulating, discuss how to hand returns if they are seen • Rig pumps will be used for displacement • Positions and expectations of all personnel involved in cement operations, have one hand in the pits specifically for strapping pits and recording volume returned. 18.3 7" Liner cement job will be a single stage. 18.4 Cement Volume Calculations: TOC: 11,142' MD / 9,339' TVD, — 698' MD above Kekiktuk As per AOGCC Reg 20 AAC 25.030(d)(5), required TOC is 500' MD or 250' TVD above hydrocarbon bearing zone, whichever is greater i. As Per 2-66A wp06, required TOC is 11142' MD / 9,339' TVD ii. More cement volume may be pumped if wellbore conditions allow Ensure cement slurry thickening time accounts for 30 min shutdown time for setting and releasing from liner hanger / packer. Confirm compressive strength sufficient for perforation. Section: Calculation Vol(bbls) Vol ft3 8.5" OH x 7" Liner: 12,092 — 11,142 x.02258 b f x 1.4 = 30.0 168.6 7" Shoe Track 120' x .038 b f= 4.6 25.8 Total Volume 34.6 194.4 18.5 18.6 18.7 Cement Slurry System ExtendaCEM Density 14.5 ppg Yield 1.333 ft3/sk Mixed Water 5.502 gal/sk Pump 5 bbls fresh water. Pressure test surface cement lines to 4000 psi. Pump 60 bbls of 11.5 ppg spacer Pump 14.5 ppg Class G Single Stage Slurry as per calculations above. Page 26 August 2018 H ffiko q. A64 , LLC END 246A Sidetrack Drilling Procedure 18.8 Drop liner wiper plug and displace with drilling mud. Target displacement rates are 4-5 bpm. • Rotate and reciprocate pipe if possible, ensure to stop before plugs land • Check to ensure displacement rates do not exceed 11.5 ppg EMW, estimated FG of Kekiktuk • Slow pumps enough to check for liner wiper plug shear release 18.9 Continue displacing cement until liner wiper plug bumps, or displacement volume has been pump. Pressure up over 1000psi to verify plug has bumped. • If plug does not bump, do not set the liner top packer, as string will be unsupported by an unset liner hanger. Discuss with Baker Rep. 18.10 Increase drill pipe pressure to set liner hanger, — 2700psi. Slack off to ensure liner hanger is set. 18.11 Increase pressure to test 7" liner t/ 3000 psi for 30 minutes, chart test. 18.12 Increase pressure to release running tool from liner hanger. Pressure up in 500 psi increments holding for 5 min each up to 4000 psi until indication that running tool has released. 18.13 Pickup to expose rotating dog sub, set down on liner and set ZXP liner top packer. 18.14 With packoff on running tool still engaged, bleed DP pressure to zero, close BOP and test 9-5/8" x 7" annulus to 3000 psi for 30 min and chart record same. Rotate and set down, if necessary to ensure liner packer is set. Bleed off pressure and open BOPE. — L -r P, `r.-07- 18.15 Pressure up t1500 psi, pickup 2-3' to verify that the HRD setting tool has released. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 18.16 Pick up above liner top. 18.17 CBU x 2, to clean up wellbore and check for any cement returns to surface or above liner top 18.18 POOH, L/D 5" DP and inspect running tools. 18.19 L/D remaining 5" DP out of derrick. Page 27 August 2018 END 2-66A Sidetrack U I Drilling Procedure nikwrp Al.kn. UA: 19.0 Perform 7" Cleanout Run & 7" CBL 19.1 PU 4" DP & MU 7" Cleanout BHA i. 5" x 4" DP tapered string ii. Ensure Cement has reached 500 psi compressive strength, minimum, prior to clean outrun 19.2 RIH, watch as BHA enters 7" liner top 19.3 Perform 7" cleanout run to top of shoe track, cleaning up any cement stringers seen 19.4 If need for perforation interval access, drill up sufficient part of the shoe track i. If any of the shoe track has been drilled, perform a second casing pressure test, 3000 psi for 30 min. 19.5 Circulate bottoms up to ensure 7" liner is clean 19.6 Displace wellbore to 8.6 ppg 3% KCL Brine 19.7 POOH 19.8 RU E -Line and run 7" CBL i. Ensure cement has reached 2000psi compressive strength before preforming CBL, this will allow cement to be detected by logging tools ii. Run CBL from PBTD to 500' above planned TOC 19.9 RD E -line. Page 28 August 2018 U iilco 1, M.A.. LLC END 2-66A Sidetrack Drilling Procedure 20.0 Contingency 6-1/8" OH x 4-1/2" Liner 20.1 In the event that the 7" liner is unable to get to TD, it will be cemented and the lowest possible depth. A 6-1/8" cleanout run / drill to TD will be performed and a contingency 4-1/2" liner will be ran. AOGCC will be notified if this contingency occurs. 20.2 RD Cement equipment, change UPR to 2-7/8" x 5" VBR and Test 20.3 PU 4" DP & MU 6-1/8" BHA. 20.4 RIH & test MWD, continue RIH to liner bottom, watch BHA as it enters liner top. 20.5 Drill out float equipment and 20' new formation. CBU and pull back into liner. 20.6 Perform FIT t/ 12.5 ppg EMW. Chart Test 20.7 Drill 6-1/8" hole to well TD 20.8 CBU x 4, 200 ft/min AV and 120 rpm 20.9 POOH and LD BHA 20.10 RU and run 4-1/2" 13Cr HE Bear liner to TD 20.11 Cement liner, ensuring entire liner has cement coverage or 500' MD above Kekiktuk is covered with cement. i. Clean out run and drilling of the liner will be performed with coil tubing post rig running well completion. 20.12 Well completion will remain the same. Page 29 August 2018 H mi....p,u. k.. u.c 21.0 Run 3-1/2" Upper Completion END 2-66A Sidetrack Drilling Procedure 21.1 M/U 3-1/2" 13Cr HE Bear gas lift completion as per tally and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 3-1/2" HE Bear M/U Torques Tubing OD Minimum Optimal Torque Maximum 3-1/2" 5,250 ft -lbs 5,810 ft -lb 6,360 ft -lbs Page 30 August 2018 H I fHe" III Va.Aa. LL1. JFEBEAR «< UNCONTROLLED DOCUMENT END 2-66A Sidetrack Drilling Procedure go August 22, 2018 JFE JFE nay p ofi cd and continues Is pedpnn opmectipn ofd qual&m8on hini ng aosonfi @ b the inpsl r33LfOJ31rd1.6Yf) nod ouslon o, 51A1dardi. Pi rormY1LG oninp line Wla%ill rdlrngs based. spaded tripe mnin mperbmv pnpertes.Pkme coimn she JFE-TC GICs for the Iiaou mformakon. Mn Y.W Sberglh 60,000 psi 552 MP, Min, YvIW Saenph 95400 list ass MP. Mn Teostk Skerglh Cc Iivq 00 95.000 Psi 3.am3 in ass MPa Small mm Cowling to Tensile Excexy 2969 n 101% 7526. 101% Ccuplinq Length 7J89 win 180.09 mm Mike snp Il Losglh 9.135 to 79.83 Tran aeaing Faso Load 89 kip 395.019 IN Pipe Body W.11 0254m 6.45 mm Pipe 10 2992 in 78.00mm Drift Diamcler 2887 in 72b2 mm Pipe C. Stella. 259 in, 1,671 mor? in� Ccllapx Pnessoe 10.50 psi 7287 up. i'don Iviiiew Pkewne 10,108psi 70.05 MP. Pipe Bldg vidtl Seength 207 kip 921 kN CONNECTION OR Cubpse Pnessum 10.540Psi 72-67 Mr. na81{BInrn iRmitim �U18 m6TaacE6 Ipt6lar System l tl PSmre u10,180"i Irflemurid 7005 MPa Jul Snorqun 207 kip 922 IN _ Just Twoule Ei anni i, 100% 180'6 Maximum Ccrnpresson Ralinq 1158 kip 737 kN Optimum Minimum a - TORQUE PA. Toque 6,250 A -lb 7,118 Nm 0,1 Toque SAID 6•Ib 7.877 him blas Shc,oldv ------ -- Mea Tarque 6.380 fl -Its 8,673 N+n -_ ................... 1An snmNer —��— 870 lab 1, 180 Nm Min Shoulder Max Shoulder -4,850 R Ils 8.375 Nen kkties rliToque4kkzhouc is to, CkmRus, Torque vs. Tums Legal Nntilbet Standard Bevel �,(( She ux of anis information is Y Bo rmdbes nsk and no eananny is impled or emresstd by JFE Steel / \ 45-' Ccoratiol wilh nesct pem one vee a nfamuwn cmlained herein_ The informan lnn this putsicaOon is /f , oul to warps or moi ificalun vre.1 nobs. P*. coobid Fo question: rewrdirp tlne dal please ertail sa�lpsire e+fyrS�G me JFE steel orce. coo or JFETGmm. H I ilcurp Alaska, U.0 21.2 Space out tubing to nearest full joint, Spot Cl Brine and Packer fluid_ END 2-66A Sidetrack Drilling Procedure 21.3 Terminate SSSV control line, Land hanger, RILDs and test hanger seals. 21.4 Drop ball and rod, pressure up and test tubing t/ 3000 psi for 30 minutes, then pressure up to 3500 psi and set packer. 21.5 Test annulus to 3000 psi f/ 30 min. C r4r 14 RT I E�-I- 21.6 Shear SOV, 2500 psi, casing to tubing. Circulate annulus through tubing to confirm shear. 21.7 Install TWC and N/D BOP. 21.8 N/U tree adapter and tree. Conduct pressure tests of same to 250/3500 psi. 21.9 Pull TWC 21.10 Circulate freeze protect down IA (500' of freeze protect is what is required at Endicott), allow freeze protect to U-tube down tubing. 21.11 Set BPV 21.12 Shut in well. 22.0 RDMO J 10 - 1--) o'3 T --e q U t v -e d 1 11, v Page 32 August 2018 23.0 Innovation Rig BOP Schematic 13-518" 5M Contrc Annular BOP 13-518" 5M Contrc Technology Doub 3-118" Kill Line 13-5/8'5M Contn Technology Singl END 2-66A Sidetrack Drilling Procedure 2-7/8" x 5-1/2" VBR Blind Rams Choke Line 2-7/8" x 5-1/2" VBR x 5M ;5M Page 33 August 2018 H IGlrorp %1.-k.. LIX 24.0 Days vs Depth 0 2000 4000 4f n 6000 v 0 a v 8000 CU 10000 12000 14000 Nage 34 END 2-66A Sidetrack Drilling Procedure END MPI 2-66A Kekiktuk UPSZ Producer 0 5 10 15 Days August2018 20 R 113.rp Al.ku, Lid: 25.0 Formation Tops & Information END 2-66A Sidetrack Drilling Procedure End 2-66A Formations (wp04) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Schrader/ West Sak 8300 6500 6539 2,943 8.65 Seabee 9300 7522 7561 3,402 8.65 Tuffs 10611 8769 8808 3,964 8.65 HRZ 11065 9206 9245 4,160 8.65 Itkilyariak 11226 9361 9400 4,230 8.65 Kekiktuk F -V 11839 9950 9989 4300 8.28 Kekiktuk F -III 1 11980 10083 1 10124 4360 8.28 Ss --k. B OY/s3/1$. w, s.ta�sol.rudelr � s below wfhduw at X500 Formation Description Drilling Notes West Sak/Schrader Wet Sand Potential for pea gravel, but should be above window depth Seabee (Colville) Silt / Mudstone-Homogeneous formation, steady drilling Tuffs Volcanic Interval with interbedded glass. Historically tough on bits and hard drilling. High torque, slow rop, abrasive and heat. HRZ Organic shale, historically unstable Historically unstable shale, sensitive to time open as well as pressure cycles between pumps on/off and surge/swab LCU Erosional surface. Historically gravel, pyrite and chert. Potential for impact damage Itkilyariak High compressive strength limestone Abrasive, high heat, slow drilling Kekiktuk Oil bearing reservoir Erratic drilling with layers of coals. Differential sticking is prevalent, keep pipe movin as much as possible Coals Coals. Possibly Eroded. Utilize coal drilling best practices. (None expected on Treat drilling breaks as coals, drilling 2-66A) 4-5' max, pull up and ream through until coal has been worked through. Goal is to wipe the hole without laying down a single Kekiktuk Oil bearing reservoir Erratic drilling with layers of coals. Differential sticking is prevalent, keep pipe movin as much as possible Page 35 August 2018 n Ilihor" ki ka. 11C 5,000' Trace of pyrite at 5330'. shale and sha.ley sand wAl, interbedded coal Is. $450' 000' TOP WEST *F 6650. 6850' 7,l)�Q' Interbedded sands and shales. Traces of Pyrite! West Sak sand group. made up of -'- six sands. good aquafer, approi total thickness 7CO' ND, Base 61 West Sak 11 7450'.7050' TVD. May be tar bearing and blind shaker screens - SAK SAl TVD P OF SEABEE r vu _ Fine sandstone at top gladdig to very fine grained sandstone to siitstone at base - 8,000, SEABEE SHALE k ► k I Abundant pyhte In SD-tD2-66 ig 9606 TVD. TOP 8700'0900' TvD I r TUFFS 3.000' (SHALE WALL) r END 2-66A Sidetrack Drilling Procedure +1-41vu IVV. I-Garl 26 126 438155 139X.24 1S2 436655 Top of Tuffs (n%\)@@++1.8700' - 8900' TVD. Shale with interbedded Tuff (volcanic glass) and ash stringers. Hard drilling and may develop ledges. UNSTABLE TUFFSH NOT A GOOD FORMATION FOR SIDETRACK KICKOFF( Had difficulty sieenng on 2-2M0-19 2003 side/rack. WARNING! POSSIBLE PRESSURE FROM CRETACEOUS INJECTION WELL AT-) 7200' TVD. Intermittent produced water injection into 2-021P-18. FMT 8.9 ppg on 1-2310.15. WATCH FOR KEYSEATS AND STUCK PIPE: 2-6011.1-13; 2-5011,11-08. 2003 SIDETRACK PROGRAM A SUCCESS. SEE LESSONS LEARNED (THIS SHEET AND SHEET 2B) Page 36 August 2018 0 Illlrorp Ala+ka, I.LI: END 2-66A Sidetrack Drilling Procedure TOP HRZ r Top of HRZ. Fissle shale interbedded with calcite. T *1- 9250% 9400' Tiroangles. Potentially unstable and more unstable at higher Follow recommended hole cleaning HRZ H procedures. Minimize ECD shocklsurgee, use adequate mud weight and circulating rate, rotate SEVERE STUCK Pipe while pumping sweeps and circulating. LC U: The LCUcuts damn to In PIPE AND TIGHT LCV: TOP ITKIL northeast target wells me Iealyarlak and poreom of the Kek*" subzune will be misung. HOLE INTERVAL! 9"'.970C,TVD Itkilyariak Itkilyariak_ Thin bedded limestone, dolomite, chart, sandstone; Hard slow drilling, may form ledges. Limestone KOEF Ilkilyariak is not present in all wells at MPI. Generally present in south 8 west flank areas of MPI. Eroded TOP OF KEKIKrUM %00`101 TVD away in crestal area. Kekiktuk Reservoir: Sand with interbedded KEKIKTUK: shales and coal. Hydrocarbon bearing, SEVERE STUCK PIPE producing horizon. AND TIGHT HOLE 246AIR-10: HRL GOOD HOLE CLEANING PROCEDURES REQUIRED. INTERVAL! 10,000• GAS! SEVERE GAS CUT MUD 2d6AlR-10; 1.47A1M-20, in SD -1212-66. Requlred 9.7 ppg. 2.241M-12 required ALSAt0. E DI3.PAD DATA q ALSO SEE SDI PAD DATA SHEET 9.6 ppg to control gasloll at TD. 240IS-22 and FOR OTHER WELLS. GOOD HOLE 1-31IM-21 required 10.7 and 10.6 ppg. Higher than CLEANING PROCEDURES normal reservoir pressure ancilor severe gas cut mud REQUIRED may be encountered requiring mud weight increases: Kekiktuk Sand (1.33BIL-24(10.3 ppg) and 2.2WO-19(10.7 ppg)). 2��4 COILED TUBING Original Ga%JOil contact at +I- 9910• TVD. SIDETRACKS: WATCH OUT FOR COALS IN MID TO LOWER STUCK PIPE IN SHALESICOALS: P3COAL KEKIKTUKIfI 3-nXJ-35, AND 1.65AIN-27. ABUNDANT COALS (P3COALS) IN THE TOP OF TIGHT HOLE IN 3.17FIK-30. THE LOWER SUBZONES {K3A INTERVAL). OTHER DIRECTIONAL PROBLEMS: P3 coals are in 2 seams, the upper 5 to 10 it 3.33PJJ-35 AND 3-17FIK-30. LO VER SUB thick and the lower 15 to 20 it thick. SEE LESSONS LEARNED (TO THE The lower appears to slough more during drilling. RIG AND SH 28 OF MPI PAD Zone 1C and Zone 1A coals. Zone lC is more of DATA SHEET. ZONE 'I C a problem. 3-037.1-33, a 1993 well, had problems with the coal in this interval. High %coal in basal 200'TVD of Kekiktuk("Zone 1"). See COAL Lessons Learned for drilling coals (2003 sidetrack program). H- 1 eEDD' Tvo Basement. hard metasediments. Page 37 August 2018 0 1111,orp M.A.. LLC 26.0 Anticipated Drilling Hazards END 2-66A Sidetrack Drilling Procedure Hole Cleaning: Maintain sufficient hole cleaning parameters (120+ rpm and 200 ft/min AV). Maintain rheology of mud system. Pump tandem sweeps as needed. 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, minimum 120. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out or troughing 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 with annular velocities of 200 ft/min or greater. 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. Differential Sticking: Ensure pipe movement and fluid flow at all time. Differential sticking has been seen across the high permeability Kekiktuk formation. Ensure LSND mud properties are in excellent shape to provide a good filter cake. Reservoir pressure is estimated to be — 8.3 ppg. MW required for shale stability is 10.3 ppg, minimum. This is over 2ppg difference. Unstable formations: Ensure proper hole cleaning practices are followed and sufficient MW is used for stability. HRZ Shale has caused stuck pipe and hole stability problems, ensure sufficient MW prior to drilling HRZ. Coals have caused packoffs and stuck pipe problems in the past. Follow good coal drilling practices. Faulting: No faults are expected. Montior resistivity and gamma ray if any indications of faults have been seen and formations have changed. H2S: Endicott MPI is designated as and 1-12S site. Personnel are to have individual 1-12S detectors and this rig will have its own 1-12S detection equipment. Ensure 1-12S monitors and detection systems are tested. 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 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S 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 at MPI. Page 38 August 2018 U I(il.0 p Alaska, LLC. 27.0 Innovation Rig Layout END 2-66A Sidetrack Drilling Procedure Page 39 August 2018 END 2-66A Sidetrack U I Drilling Procedure 11H.,p ANA., LLC 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. Page 40 August 2018 U lhl,—p A1.4., u.c 29.0 Innovation Choke Manifold Schematic END 2-66A Sidetrack Drilling Procedure Page 41 August 2018 R rlikorp Alueka, LLC END 2-66A Sidetrack Drilling Procedure 30.0 Casing Design Information 11 Calculation & Casing Design Factors milco�r Endicott MPI DATE: 8.22.2018 WELL: 2-66A DESIGN BY: Joe Engel Design Criteria: Hole Size 8-1/2" Mud Density: 10.3 ppg Drilling Mode MASP(8.5'): 3,496 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Max MW gradient external stress and the casing evacuated for the internal stress Casino Section Calculation/Specification 1 Casing OD T Top (MD) 7,500 Top (TVD) 5,930 Bottom (MD) 12,092 Bottom (TVD) 10,233 Length 4,592 Weight (pp0 26 Grade L-0 Connection DWC Weight w/o Bouyancy Factor (lbs) 119,392 Tension at Top of Section (lbs) 119,392 Min strength Tension (1000 lbs) 604 Worst Case Safety Factor (Tension) 5.06 Collapse Pressure at bottom (Psi) 4,100 Collapse Resistance w/o tension (Psi) 5,410 Worst Case Safety Factor (Collapse) 1.32 MASP (psi) 3,496 Minimum Yield (psi) 7,240 Worst case safety factor (Burst) 2.07 Page 42 August 2018 U na",..r Al.k". UJ END 2-66A Sidetrack Drilling Procedure 31.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2" intermediate Hole Section H11c2-T MPi 2-66A Endicott MD TVD Planned Top: 7500 5930 Planned TD: 12,092 10233 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Kekiktuk 9989 430D I Oil &3 0.430 offset Well Mud Densities W.1i MW anon Ton ITVDI Rottnm (TVDI Date 4-26A 10.30 5,395 9,890 Aug -2018 3-23A 10.30 9,905 10,121 Jul -2017 Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi /ft based on field test data. 2. Maximum planned mud density for the 8-1/2" hole section is 10.8 ppg. 3. Calculations assume Kekiktukreserviorcontains 1000Agas (worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 9-5/8" Shoe/Window 75W MD / 593Y TVD 5930(ft)x0.7(psi/ft)= 4,151.00 4151(psi)-[0.1(psi/ft)*5930(ft))= 3558 si Drilling Mode MASP MASP from pore pressure (wellbore completely evacuated to gas) Kekiktuk is below normal pressure at.43 psi/TVD Deepest formation at .45 psi/ND 10233(ft) x 0.43(psi/ft)= 4400 psi 4400(psi)-[0.1(psi/ft)*30233(ft))= 3377 si 9989(ft) x 0.45(psi/ft)= 4495 psi 4495(psi)-[0.1(psi/ft)*9989(ft))= 3496 psi Summary: 1. MASP while drilling 8-1/2" Intermediate hole is governed by the wellbore completely evacuated togas from the Kekiktuk Reservior Page 43 August 2018 H Ili6rorp M. A.. 1.1.1: 32.0 Spider Plot (NAD 27) (Governmental Sections) \Sec. 26- - \ 1 __ - __- ____ -r Sec. 35 35 1 x.0 - - - - - -- c c _ ,040 2fi6A BHL - �1 c 2 1 d 2-66A_TPH 1 ;5 yl� 1 1 1 • 1 1 - 1 t 1 1 1 Sec 2 1 1 1 I 1 1 I I END 2-66A Sidetrack Drilling Procedure �,\ \ � \ ,♦ Sec. 25 /� / of \ ♦ �� EFEOFAUOR- 6\L.1N D; v it MR cs. a J012N016E--------------``_-^>_-66.A-SHL A011:034633- - - _ - _ S�: 36.E ___ mss- ♦- N //I ♦tip " I DUCK isa UN j P / / V + r l I , I I / I I 1 I f l � ADL034636 U I11NO16E / / Duck Island Unit END 2-66A Well Legend • 2-66A SHL Other SurAace Holies (SHL) X 2-66A_TPH Other Bott= Hales (BHL) Other Well Paths T 2-66A-BHL O at and Gas Unit Boundary Pad Footprint Alaska State, Plane Zone 3 NAD 1927 0 500 1,000 1.500 2,000 Feet Page 44 August 2018 33.0 Surface Plat (As Built) (NAD 27) �$ U IS 2 0 2 -OB ■ _09 r » 2-20 ■ i -is 2-22 . C i -i 2-W ■ 2-26 ■ . ,-25 28 ■ ' 1-29 2- ■ 29 Z -j= ■ . 1-31 2_14 ■ .I -S 2-76 ■ _ ;-m 2-x ■ 2 -KI ■ 1- 2-42 ■ ■ 1-44u1 2-41 1_451 2-46 47 21-49 ,:W 1-51 52 2-54 111yy 96 : 1-57 2-50 C 1:57 2-02 ■ 1-6L 2-e8 2-811 0 1-0] 2 -TO ■ ■ 1-09 END 2-66A Sidetrack Drilling Procedure SURVEYOR'S CERTIFICATE 11(B(8Y MIFY MAT 1 m PROEFILY INNITEAED AND UEENI ED III P Ilm LAM) SUINLYND W MPI ME MAX -B MA9G AI® MAL TIis A" m R(PR m MY A SCTYCT YAM BT YE DB mm W DIRECT OWEIISIONS AYO NE ALL ONFIEET S Np AML M,LALS APE COAECT AS Of ARYL b 2011 COA No.: AECC582 LFGE�NQ NOTES: y A5-BULT DONWCNa 1. AL W STATE PUN; COURDNATI3 ARE LUKE A WD27. 2. BASS K LOCAIKW IS EmMCOiT KN YUIUAN75 W-1. ■ LICSTWD 00MUCT06 I (LEYAIICN DAM IS WS- GRAPHIC SCALE A DEDD7TID POSITIONS ME NAD21. S PID WEAN SCIEC (ACTIN, Is 0.129983559 D SD IN 3W 6 m,E 6 "WT. MAIL 1D, 2DIB MID WAY 23. 2MB. ( IN i6LT 7. RERKOKE ME eDMO 14118-02 " DD -OB 1 YNA - IN N. KID -02 0.73 ., v o lar Imus urRN]IAN. ALASKA ItNilcorp Alaska ENDIDIICOTT MPI AS -BUILT CONDUCTOR 1 s WELL. 2-66 Page 45 August 2018 WELL cwn,w m.,,........ ..........�,...._. A.S.P. PLANT .. .- . .. ._ _ _.........._._ GEODETIC GEODETIC _ CE SECTION NO. I COORDINATES COORDINATES POSITION(OMS) PO-SITICN(D.DD) BOX ELEV. OFFSETS I Y-5,962.293.29' N=2,535.94' N 7011'08.101 N 70.3522503' 13.3' 3,152' FSLI ' 2-66 %= 256 640 95 I E 2 640 35' W 1475730 215" W 147.9583931' - 2,360 FEL ItNilcorp Alaska ENDIDIICOTT MPI AS -BUILT CONDUCTOR 1 s WELL. 2-66 Page 45 August 2018 R 11H.q M.A.. LLC END 2-66A Sidetrack Drilling Procedure 34.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD ro 5.000 POeBodyWanThidwess ml 0.362 Pipe Body Grade S135 Drill Pipe Length 5 Connection GPDS50 Tod Joint OD 6.625 Tod Joint lD r^. 3250 Pin Tong 9 box Tong m112 80 %Inspection Class Nmu1al Weight Designation API Premwn Class 19.50 Dn11 Pipe Approximate Length m,131 5 Smoot hEdge Height nti 3(32 Raised Tod Joint SMYS .y 120 000 Upset Type IEU Max Upset OD (OTE) ,.� 5.125 Friction Fads 1.0 . Two <ox<+.n n[wx h.CWq v Drill Pipe Performance Drill -Pipe Length Rangel Pipe Body at 100 F Tension 0 56000 �w..++<e1 .8 gory Size <m 3.125 - - _ sa<w 32.100 1467.400 1 � au <.o<a.an*m.vm+1<e<�e rs.vrc<erc...r m we m pa Doer mm me.vm..nela ax-� dm.e wn amn 1rn.. Connection Performance GPDS50 ( 6.625 int OD X 3.250 mh ID ) 120.000 m� IbY Tn mYNP<<Tnw•vn o-%ri JII<n<4.ivJT rt<i-I: Yp (LJC<iLWpD<i[<16J MJoM Torsional StrenpM 0eeo 71.800 JOM Tensile Strenoth inn 1250.000 Elevator Shoulder Information SmoothEdpe Height 332 Raised Box oD Elevator -CIO,,tY . 1.658.000 Assumed Elevator Bore Diameter 5.219 Pipe Body Slip Crushing Capacity ®V Tool Joint Dimensions Satw"d 00 m 6.435 . Tow. m a w v,wnu^aw w 5.930 r�rowx 00m< 5.93 cou+wew• w4 3132 Raised 6.812 mr API Premium Class eWC E. -M YLeC m eavmsO Elev.<l EdC. roR�� mb. wa [miia <eeisw ,w.,wAo emx • mneo ex+aw oo mu<.ivs wevaw emnv.aun vmeu.e i.ow.y � POD Body uftfiip on ( 5 - OD 0.362 w Wall S-135) Pipe Bodv Performance K -r Grein Pp Body ( 5 m) OD 0.362 m Wall S-135) Page 46 August 2018 aPi Nominal 80 % UMection Class API Premwn Class Pipe Tensile Strength 7121 560.800 Pipe Tasbnal strength 74.100 58.100 58.100 T&PweSody Twsiarel Ratio 027 1.24 1.24 80% Pipe TorsionalStength 59300 46500 46.500 Bust 17.105 15,638 15.638 Coes «+ 15.672 10.029 10.029 Pipe OD on 5.000 4.855 4.855 Wao TUckness 0.362 10290 0.290 Nominal Pipe ID w 4-176 14276 4276 Cross Sectional Area of Pipe Sod wr , 5.275 4.156 4.15: Cross sectional Area of OD ora 19.635 18.514 18.514 Cross Sectional Area of ID wn 14.360 14.360 14.360 section ModMn wn 5.708 14.476 4.476 Polar season Moddus ro'x- / i.415 18.953 8.953 Page 46 August 2018 aPi W Weatherford 5" 19.50 Ibfft S-135 w/ NC 50 6-518" OD x 3-1/4" ID Tool Joint END 2-66A Sidetrack Drilling Procedure 500204050016200 DRILL PIPE SPECIFICATIONS Grade S-135 Connection NC 50 Interchangeable With 5- XH & 4-12' IF Upset Type IEU Nominal Weight per Foot 1950.lbs Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-518- Inside Diameter 3-114' API Drift 3-118' Rabbit OD. Suggested 3-1116" Minimum Make-up Torque 25.900 ft -lbs Maximum Recommend Make-up Torque 26,800 ft -lbs Torsional Yield Strength 51.700 ft -lbs Tensile Strength 1,269,000 lbs TUBE DATA New Premium Outside Diameter 5.000' 4.855' Inside Diameter 4.276" 4.276' Wall Thickness 0.362" 0.290' Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook Load/tensile Strength 712,000 lbs 560,800 lbs Slip Crushing I Slip Type (SDXL) 572,100 lbs 453,500 lbs Burst Pressure 17,100 psi 16.100 psi Collapse Pressure 15,700 psi 10.000 psi Torsional Yield Strength 74.100 tt-lbs 58.100 ft -lbs Capacity WI Tool Joint 0.726 US aVR 0.726 US oallft Displacement WI Tool --1J 0.353 US oaVft 0.322 US gaUft Page 47 Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss, damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. August 2018 Hilcorp Alaska, LLC Duck Island Unit End MPI Plan: DIU 2-66A Plan: 2-66A Plan: 2-66A WP04 Standard Proposal Report 18 July, 2018 HALLIBURTON Sperry Drilling Services c 4500- 5250 500- 5250 n m O I 6000- 1= is 6750 F- 7500 1 1 Hilcory Alaska, LLC REFERENCE INFORMATION NALLIBURTON 0 +E/ -W Northing Easting Latittude Longitude 0.00 5982293.29 258840.95 70° 21'8.101 N 147° 57' 30.215 W Co-ordinate (N/E) Reference: Well Plan: DIU 2-66A, True North Calculation Method: Minimum Curvature Depth To Survey/Plan Tool 7482.80 2-66 Gymdats CT Rate Gyro (258 PB1) 2_Gyro-NS-CT_Csg+Cent 7880.00 2-66A WP04(Plan: 256A) 2_ MWD_Interp Azi+Sag 1209298 2-66A WP04(Plan: 256A) 2_MWD+IFR2+MS*Sag Project. Eno, System: ISCWSA Vertical (TVD) Reference: DIU 2-66A w03 RKB@ 39.80usR(Innovation) spa,v 0HIIing ND TVDSS MD Size Name Site: Scan Method: Closest Approach 3D Measured Depth Reference: DIU 2-66Aw 03 RKB @ 39.80usft (Innovation) Well: Error Surface: Elliptical Conic Calculation Method: Minimum Curvature loon Wellbore: Warning Melhcd: Error Ratio DDI = 6.027 8808.80 8769.00 10611.22 TUFF Design: 2-66A WP04 SECTION DETAILS ec MD 1 7482.80 Inc 45.68 Azi 228.51 ND +N/ -S +E/ -W Clog TFace VSect Target Annotation 5918.75 -2408.99 -3123.62 0.00 0.00 3830.64 9400.60 9361.00 11226.97 TITK 2 7500.00 45.62 228.86 5930.77 -2417.11 -3132.85 1.50 103.60 3842.37 KOP : Start Dir 12.29'/100': 7500' MD, 5930.77'TVD 3 7517.00 46.67 231.37 5942.55 -2424.97 -3142.26 12.29 60.00 3854.15 End Dir : 7517' MD, 5942.55' TVD 4 7547.00 46.67 231.37 5963.14 -2438.59 -3159.31 0.00 0.00 3875.25 Stan Dir doll 00' : 7547' MD, 5963.14-rVD 5 8817.12 15.97 329.36 7083.92 -2586.50 -3641.18 4.00 159.42 4375.80 End Dir :8817.12' MD, 7083.92'rVD 611839.61 15.97 329.36 9989.80 -1871.16 -4064.97 0.00 0.00 4474.42 MPI 2-66ATgl -750 712092.78 15.97 329.36 10233.20 -1811.24 -4100.47 0.00 0.00 4482.68 Total Depth: 12092.78' MD, 10233.2' TVD c 4500- 5250 500- 5250 n m O I 6000- 1= is 6750 F- 7500 1 1 WELL DETAILS: Plan: DIU 2-66A Ground Level: 13.30 0 +E/ -W Northing Easting Latittude Longitude 0.00 5982293.29 258840.95 70° 21'8.101 N 147° 57' 30.215 W SURVEY PROGRAM epth From 32.80 7482.80 7880.00 Depth To Survey/Plan Tool 7482.80 2-66 Gymdats CT Rate Gyro (258 PB1) 2_Gyro-NS-CT_Csg+Cent 7880.00 2-66A WP04(Plan: 256A) 2_ MWD_Interp Azi+Sag 1209298 2-66A WP04(Plan: 256A) 2_MWD+IFR2+MS*Sag Project. Duck Island Unit 500 ND TVDSS MD Size Name Site: End MPI 5930.77 5890.97 7500.00 9-5/8 95/8"TOW Well: Plan: DIU 2-66A 750 loon Wellbore: Plan: 2-66A 8808.80 8769.00 10611.22 TUFF Design: 2-66A WP04 c 4500- 5250 500- 5250 n m O I 6000- 1= is 6750 F- 7500 1 1 KOP : Start Dir 12.29°/100' : 7500' MD, 5930.77'ND, 60° RT TF End Dir : 7517' MD, 5942.55' ND QOO -------- Start Dir 4°/100' : 7547' MD, 5963.14'TVD 0 ro OEnd Dir :8817.12' MD, 7083.92' ND 8 0 0yg 00 9000 00 w O yo 9500 ^O 00 ^^O 00 TUFF 10500 ^ry0 - - y00 1 THRZ - - - _ _ 11000 - iC4J TITK - -_ ,60� 11500 N MPI 2-66A Tgt 2.66 Pat 1oyoo --FV __- _ ..... _ .. _ _. _.. 993 NO Total Depth :12092.78' MD, 10233.2ND ANo- 2-66A WP04 A5209 2-66 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 246.17° (1500 usfVin) P WELL DETAILS: Plan: DIU 2-66A Ground Level: 13.30 +N/ -S 0.00 +E/ -W Northing Easting Latittude Longitude 0.00 5982293.29 258840.95 70° 21'8.101 N 147° 57' 30.215 W SURVEY PROGRAM epth From 32.80 7482.80 7880.00 Depth To Survey/Plan Tool 7482.80 2-66 Gymdats CT Rate Gyro (258 PB1) 2_Gyro-NS-CT_Csg+Cent 7880.00 2-66A WP04(Plan: 256A) 2_ MWD_Interp Azi+Sag 1209298 2-66A WP04(Plan: 256A) 2_MWD+IFR2+MS*Sag CASING DETAILS. ND TVDSS MD Size Name 5930.77 5890.97 7500.00 9-5/8 95/8"TOW 10233.20 1019140 12092.78 7 7" x 8 1/2" FORMATION TOP DETAILS NDPath NDssPath MDPath Formation 8808.80 8769.00 10611.22 TUFF 9245.80 9206.00 11065.75 THRZ 9400.80 9361.00 11226.97 LCU 9400.60 9361.00 11226.97 TITK 9989.80 9950.00 11839.61 FV KOP : Start Dir 12.29°/100' : 7500' MD, 5930.77'ND, 60° RT TF End Dir : 7517' MD, 5942.55' ND QOO -------- Start Dir 4°/100' : 7547' MD, 5963.14'TVD 0 ro OEnd Dir :8817.12' MD, 7083.92' ND 8 0 0yg 00 9000 00 w O yo 9500 ^O 00 ^^O 00 TUFF 10500 ^ry0 - - y00 1 THRZ - - - _ _ 11000 - iC4J TITK - -_ ,60� 11500 N MPI 2-66A Tgt 2.66 Pat 1oyoo --FV __- _ ..... _ .. _ _. _.. 993 NO Total Depth :12092.78' MD, 10233.2ND ANo- 2-66A WP04 A5209 2-66 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 246.17° (1500 usfVin) P (um/)Jsn 006) (+)y1.loN/(-)47nuS v IT 3 ro -- z gym � z 0 Fdd�i� ta- -»= 3ooE z O "'„S Uw`m w K yy @�C a J EYEm =�oq z U �c Zo (um/)Jsn 006) (+)y1.loN/(-)47nuS v IT HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Duck Island Unit Site: End MPI Well; Plan: DIU 2-66A Wellbore: Plan: 2-66A Design: 2-66A WP04 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: DIU 2-66A TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) MO Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) North Reference: True Survey Calculation Method: Minimum Curvature , 'roject Duck Island Unit, North Slope, UNITED STATES Site Position: lap System: US State Plane 1927 (Exact solution) - System Datum: Mean Sea Level Using Well Reference Point leo Datum: NAD 1927 (NADCON CONUS) Well Plan: DIU 2-66A lap Zone: Alaska Zone 03 Using geodetic scale factor Site End MPI, TR -12-16 Plan: 2-66A Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: DIU 2-66A Well Position +NIS 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Plan: 2-66A Magnetics Model Name Sample Date BGGM2018 8/15/2018 Design 2-66A WP04 Version: Phase: Vertical Section: Depth From (TVD) (usft) 26.50 5,979,337.49 usft Latitude: 256,681.13usft Longitude: 0" Grid Convergence: 5,982,293.29 usft Latitude: 258,840.95 usfl Longitude: 13.30 us0 Ground Level: 70° 20'38.358 N 147° 58'30.505 W -1.86 ° 70° 21'8.101 N 147° 57'30.215 W 13.30usft - Declination Dip Angle Field Strength (°) (I (nT) 17.48 81.05 57,461 PLAN Tie On Depth: 7,482.80 +N/.S +FJ -W Direction (usft) (usft) (°) 0.00 0.00 246.17 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/S +E/ -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°I100usft) (°) 7,482.80 45.68 228.51 5,918.75 5,878.95 -2,408.99 -3,123.62 0.00 0.00 0.00 0.00 7,500.00 45.62 228.86 5,930.77 5,890.97 -2,417.11 -3,132.85 1.50 -0.35 2.03 103.60 7,517.00 46.67 231.37 5,942.55 5,902.75 -2,424.97 -3,142.26 12.29 6.15 14.63 60.00 7,547.00 46.67 231.37 5,963.14 5,923.34 -2,438.59 -3,159.31 0.00 0.00 0.00 0.00 8,817.12 15.97 329.36 7,083.92 7,044.12 -2,586.50 -3,641.18 4.00 -2.42 7.71 159.42 11,839.61 15.97 329.36 9,989.80 9,950.00 -1,871.16 -4,064.97 0.00 0.00 0.00 0.00 12,092.78 15.97 329.36 10,233.20 10,193.40 -1,811.24 -4,100.47 0.00 0.00 0.00 0.00 7/182018 11:38:06AM Page 2 COMPASS 5000.1 Build 81E Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Coordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Design: 2-66A WP04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (_) (I (usft) usft (usft) (usft) (usft) (usft) -13.30 26.50 0.00 0.00 26.50 -13.30 0.00 0.00 5,982,293.29 258,840.95 0.00 0.00 32.80 0.29 216.98 32.80 -7.00 -0.01 -0.01 5,982,293.28 258,840.94 4.60 0.01 57.80 0.37 201.95 57.80 18.00 -0.14 -0.08 5,982,293.15 258,840.87 0.47 0.13 82.80 0.31 206.03 82.80 43.00 -0.27 -0.14 5,982,293.02 258,840.80 0.26 0.24 107.80 0.35 205.10 107.80 68.00 -0.40 -0.20 5,982,292.89 258,840.74 0.16 0.35 132.80 0.33 210.46 132.80 93.00 -0.53 -0.27 5,982,292.76 258,840.66 0.15 0.46 157.80 0.30 207.95 157.80 118.00 -0.65 -0.34 5,982,292.65 258,840.59 0.13 0.57 182.80 0.30 196.57 182.80 143.00 -0.78 -0.39 5,982,292.53 258,840.54 0.24 0.67 207.80 0.41 184.56 207.80 168.00 -0.93 -0.41 5,982,292.38 258,840.51 0.53 0.75 232.80 0.45 178.17 232.80 193.00 -1.11 -0.41 5,982,292.19 258,840.50 0.25 0.83 257.80 0.48 191.65 257.80 218.00 -1.32 -0.43 5,982,291.99 258,840.47 0.45 0.93 282.80 0.43 182.56 282.79 242.99 -1.51 -0.46 5,982,291.79 258,840.44 0.35 1.03 307.80 0.56 181.44 307.79 267.99 -1.73 -0.47 5,982,291.58 258,840.43 0.52 1.12 332.80 0.61 175.81 332.79 292.99 -1.98 -0.46 5,982,291.32 258,840.43 0.30 1.22 357.80 0.53 179.22 357.79 317.99 -2.23 -0.45 5,982,291.08 258,840.43 0.35 1.31 382.80 0.57 174.69 382.79 342.99 -2.47 -0.43 5,982,290.84 258,840.44 0.24 1.40 407.80 0.63 196.39 407.79 367.99 -2.73 -0.46 5,982,290.58 258,840.40 0.93 1.52 432.80 0.96 220.94 432.79 392.99 -3.02 -0.64 5,982,290.30 258,840.22 1.87 1.80 457.80 1.53 231.97 457.78 417.98 -3.38 -1.04 5,982,289.95 258,839.80 2.46 2.31 482.80 2.17 237.81 482.77 442.97 -3.84 -1.70 5,982,289.51 258,839.13 2.67 3.11 507.80 2.70 240.24 507.74 467.94 -4.38 -2.61 5,982,288.99 258,838.20 2.16 4.16 532.80 3.26 241.07 532.71 492.91 -5.02 -3.75 5,982,288.40 258,837.04 2.25 5.45 557.80 3.44 241.21 557.67 517.87 -5.72 -5.03 5,982,287.73 258,835.74 0.72 6.91 582.80 3.57 241.31 582.62 542.82 -6.46 -6.37 5,982,287.04 256,834.38 0.52 8.43 607.80 3.46 241.06 607.57 567.77 -7.20 -7.71 5,982,286.35 258,833.01 0.44 9.96 632.80 3.28 240.68 632.53 592.73 -7.91 -8.99 5,982,285.67 258,831.71 0.73 11.42 657.80 3.06 240.08 657.49 617.69 -8.59 -10.19 5,982,285.03 258,830.48 0.89 12.80 682.80 3.03 239.81 682.46 642.66 -9.26 -11.34 5,982,284.40 258,829.31 0.13 14.12 707.80 3.04 240.25 707.42 667.62 -9.92 -12.49 5,982,283.78 258,828.15 0.10 15.43 732.80 3.07 241.31 732.39 692.59 -10.57 -13.65 5,982,283.16 258,826.96 0.26 16.76 757.80 3.17 243.70 757.35 717.55 -11.20 -14.86 5,982,282.58 258,825.74 0.66 18.12 782.80 3.34 246.24 782.31 742.51 -11.80 -16.15 5,982,282.02 258,824.43 0.89 19.54 807.80 3.65 249.75 807.26 767.46 -12.37 -17.56 5,982,281.49 258,823.00 1.51 21.06 832.80 3.78 250.94 832.21 792.41 -12.91 -19.09 5,982,281.00 258,821.46 0.60 22.68 857.80 3.89 251.96 857.15 817.35 -13.44 -20.67 5,982,280.52 258,819.86 0.52 24.34 882.80 3.94 251.82 882.10 842.30 -13.97 -22.29 5,982,280.04 258,818.22 0.20 26.04 907.80 3.95 251.62 907.04 867.24 -14.51 -23.93 5,982,279.55 258,816.57 0.07 27.75 932.80 3.97 251.48 931.98 892.18 -15.06 -25.56 5,982,279.06 258,814.92 0.09 29.47 957.80 4.05 250.88 956.92 917.12 -15.62 -27.22 5,982,278.55 258,813.24 0.36 31.21 982.80 4.06 249.73 981.85 942.05 -16.22 -28.88 5,982,278.01 258,811.56 0.33 32.97 1,007.80 4.08 247.79 1,006.79 966.99 -16.86 -30.54 5,982,277.42 258,809.89 0.56 34.75 1,032.80 4.13 246.43 1,031.73 991.93 -17.56 -32.19 5,982,276.78 258,808.22 0.44 36.54 1,057.80 4.20 244.93 1,056.66 1,016.86 -18.31 -33.84 5,982,276.08 258,806.54 0.52 38.35 1,082.80 4.22 243.89 1,081.59 1,041.79 -19.10 -35.49 5,982,275.34 258,804.86 0.32 40.19 1,107.80 4.28 242.64 1,106.52 1,066.72 -19.93 -37.15 5,982,274.56 258,803.18 0.44 42.04 7/182018 11:38:06AM Page 3 COMPASS 5000.1 Build 81E HALLIBURTON Halliburton Standard Proposal Report Database: Sperry EDM - NORTH US+ CANADA Local Co-ordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Design: 2-66A WP04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI -S +EI -W Northing Easting DLS Vert Section (usft) (°) (I (usft) usft (usft) (usft) (usft) (usft) 1,091.65 1,132.80 4.35 241.67 1,131.45 1,091.65 -20.81 -38.81 5,982,273.74 258,801.49 0.40 43.91 1,157.80 4.41 240.97 1,156.38 1,116.58 -21.73 -40.49 5,982,272.88 258,799.79 0.32 45.81 1,182.80 4.48 240.89 1,181.30 1,141.50 -22.67 -42.18 5,982,271.99 258,798.06 0.28 47.74 1,207.80 4.50 240.57 1,206.23 1,166.43 -23.63 -43.89 5,982,271.09 258,796.33 0.13 49.69 1,232.80 4.66 240.70 1,231.15 1,191.35 -24.61 -45.63 5,982,270.17 258,794.56 0.64 51.68 1,257.80 4.67 240.15 1,256.07 1,216.27 -25.61 -47.40 5,982,269.22 258,792.76 0.18 53.70 1,282.80 4.96 240.51 1,280.98 1,241.18 -26.65 -49.22 5,982,268.24 258,790.90 1.17 55.79 1,307.80 5.35 241.27 1,305.88 1,266.08 -27.74 -51.18 5,982,267.21 258,788.90 1.58 58.03 1,332.80 5.78 241.62 1,330.76 1,290.96 -28.90 -53.31 5,982,266.12 258,786.74 1.73 60.44 1,357.80 6.28 242.82 1,355.62 1,315.82 -30.12 -55.64 5,982,264.98 258,784.38 2.06 63.06 1,382.80 6.59 243.46 1,380.46 1,340.66 -31.39 -58.14 5,982,263.79 258,781.84 1.27 65.86 1,407.80 6.87 244.06 1,405.29 1,365.49 -32.68 -60.76 5,982,262.58 258,779.17 1.15 68.79 1,432.80 7.32 244.26 1,430.10 1,390.30 -34.03 -63.54 5,982,261.33 258,776.35 1.80 71.87 1,457.80 7.90 244.88 1,454.88 1,415.08 -35.45 -66.53 5,982,260.00 258,773.31 2.34 75.18 1,482.80 8.85 245.01 1,479.61 1,439.81 -36.99 -69.83 5,982,258.57 258,769.97 3.80 78.82 1,507.80 9.81 244.59 1,504.28 1,464.48 -38.72 -73.50 5,982,256.96 258,766.25 3.85 82.88 1,532.80 10.58 243.56 1,528.89 1,489.09 -40.65 -77.48 5,982,255.15 258,762.21 3.17 87.30 1,557.80 11.53 242.87 1,553.42 1,513.62 -42.81 -81.76 5,982,253.13 258,757.86 3.84 92.08 1,582.80 11.83 242.01 1,577.90 1,538.10 45.16 -86.24 5,982,250.93 258,753.30 1.39 97.13 1,607.80 12.04 241.22 1,602.36 1,562.56 -47.61 -90.79 5,982,248.62 258,748.68 1.06 102.29 1,632.80 12.46 239.81 1,626.79 1,586.99 -50.23 -95.41 5,982,246.16 258,743.98 2.06 107.57 1,657.80 12.86 238.87 1,651.19 1,611.39 -53.02 -100.12 5,982,243.52 258,739.18 1.80 113.01 1,682.80 13.41 237.86 1,675.53 1,635.73 -56.00 -104.96 5,982,240.70 258,734.25 2.38 118.63 1,707.80 14.40 236.56 1,699.80 1,660.00 -59.26 -110.00 5,982,237.61 258,729.10 4.15 124.57 1,732.80 15.18 235.40 1,723.97 1,684.17 -62.83 -115.29 5,982,234.21 258,723.70 3.34 130.85 1,757.80 15.94 234.23 1,748.05 1,708.25 -66.69 -120.77 5,982,230.52 258,718.10 3.29 137.42 1,782.80 16.20 234.06 1,772.08 1,732.28 -70.75 -126.38 5,982,226.65 258,712.36 1.06 144.19 1,807.80 16.63 233.95 1,796.06 1,756.26 -74.90 -132.10 5,982,222.68 258,706.51 1.72 151.10 1,832.80 17.77 234.11 1,819.94 1,780.14 -79.24 -138.08 5,982,218.54 258,700.39 4.56 158.32 1,857.80 18.38 234.09 1,843.71 1,803.91 -83.79 -144.36 5,982,214.19 258,693.97 2.44 165.91 1,882.80 18.95 233.91 1,867.39 1,827.59 -88.49 -150.84 5,982,209.70 258,687.35 2.29 173.73 1,907.80 19.92 233.82 1,890.97 1,851.17 -93.40 -157.55 5,982,205.02 258,680.48 3.88 181.86 1,932.80 20.67 233.70 1,914.41 1,874.61 -98.52 -164.55 5,982,200.12 258,673.32 3.00 190.33 1,957.80 21.47 233.61 1,937.74 1,897.94 -103.85 -171.79 5,982,195.03 258,665.91 3.20 199.10 1,982.80 22.34 233.28 1,960.94 1,921.14 -109.41 -179.28 5,982,189.72 258,658.25 3.51 208.20 2,007.80 23.13 232.96 1,983.99 1,944.19 -115.20 -187.01 5,982,184.17 258,650.34 3.20 217.61 2,032.80 24.36 232.55 2,006.88 1,967.08 -121.30 -195.02 5,982,178.34 258,642.13 4.96 227.40 2,057.80 25.16 232.69 2,029.58 1,989.78 -127.65 -203.34 5,982,172.25 258,633.61 3.21 237.58 2,082.80 25.94 232.76 2,052.13 2,012.33 -134.18 -211.92 5,982,166.00 258,624.83 3.12 248.07 2,107.80 27.24 233.00 2,074.49 2,034.69 -140.94 -220.84 5,982,159.54 258,615.69 5.22 258.96 2,132.80 27.93 233.14 2,096.65 2,056.85 -147.89 -230.10 5,982,152.89 258,606.22 2.77 270.23 2,157.80 28.58 233.24 2,118.67 2,078.87 -154.98 -239.57 5,982,146.10 258,596.52 2.61 281.77 2,182.80 29.17 233.33 2,140.56 2,100.76 -162.20 -249.25 5,982,139.20 258,586.62 2.37 293.54 2,207.80 29.49 233.43 2,162.36 2,122.56 -169.50 -259.08 5,982,132.22 258,576.56 1.29 305.48 2,232.80 29.81 233.57 2,184.08 2,144.28 -176.86 -269.02 5,982,125.19 258,566.39 1.31 317.54 7/182018 11:38:06AM Page 4 COMPASS 5000.1 Build 81E Halliburton H A L L I B U R T O N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A TVDss Design: 2-66A WP04 +EI -W Northing Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NlS +EI -W Northing Easting DLS Vert Section (usft) (1) (') (usft) usft (usft) (usft) (usft) (usft) 2,165.95 2,257.80 30.01 233.69 2,205.75 2,165.95 -184.25 -279.06 5,982,118.12 258,556.12 0.84 329.71 2,282.80 30.22 233.77 2,227.38 2,187.58 -191.67 -289.17 5,982,111.03 258,545.77 0.86 341.96 2,307.80 30.26 234.02 2,248.98 2,209.18 -199.09 -299.34 5,982,103.94 258,535.36 0.53 354.26 2,332.80 30.13 234.25 2,270.58 2,230.78 -206.46 -309.53 5,982,096.91 258,524.94 0.70 366.56 2,357.80 30.01 234.41 2,292.22 2,252.42 -213.76 -319.71 5,982,089.93 258,514.54 0.58 378.82 2,382.80 29.82 234.73 2,313.89 2,274.09 -220.99 -329.87 5,982,083.04 258,504.15 0.99 391.03 2,407.80 29.87 234.85 2,335.57 2,295.77 -228.17 -340.03 5,982,076.19 258,493.76 0.31 403.23 2,432.80 29.91 234.99 2,357.25 2,317.45 -235.33 -350.23 5,982,069.37 258,483.34 0.32 415.45 2,457.80 30.14 234.91 2,378.89 2,339.09 -242.51 -360.47 5,982,062.52 258,472.87 0.93 427.72 2,482.80 30.46 234.75 2,400.48 2,360.68 -249.77 -370.78 5,982,055.59 258,462.34 1.32 440.09 2,507.80 30.95 234.53 2,421.97 2,382.17 -257.16 -381.19 5,982,048.54 258,451.69 2.01 452.60 2,532.80 31.16 234.65 2,443.39 2,403.59 -264.63 -391.70 5,982,041.41 258,440.95 0.88 465.23 2,557.80 31.16 234.78 2,464.78 2,424.98 -272.11 -402.26 5,982,034.28 258,430.15 0.27 477.91 2,582.80 30.91 235.07 2,486.20 2,446.40 -279.51 -412.81 5,982,027.22 258,419.37 1.17 490.55 2,607.80 30.88 235.14 2,507.66 2,467.86 -286.86 -423.34 5,982,020.22 258,408.61 0.19 503.15 2,632.80 30.93 235.08 2,529.11 2,489.31 -294.20 -433.87 5,982,013.21 258,397.85 0.23 515.75 2,657.80 30.96 234.81 2,550.55 2,510.75 -301.59 -444.39 5,982,006.17 258,387.09 0.57 528.36 2,682.80 31.07 234.68 2,571.98 2,532.18 -309.02 -454.91 5,981,999.08 258,376.34 0.52 540.99 2,707.80 31.01 234.61 2,593.40 2,553.60 -316.48 -465.43 5,981,991.96 258,365.59 0.28 553.62 2,732.80 30.79 234.74 2,614.85 2,575.05 -323.90 -475.90 5,981,984.88 258,354.89 0.92 566.20 2,757.80 30.65 234.81 2,636.34 2,596.54 -331.27 486.33 5,981,977.86 258,344.22 0.58 578.72 2,782.80 30.52 234.89 2,657.86 2,618.06 -338.59 496.73 5,981,970.87 258,333.59 0.54 591.19 2,807.80 30.47 234.99 2,679.40 2,639.60 -345.88 -507.12 5,981,963.92 258,322.98 0.28 603.63 2,832.80 30.57 235.09 2,700.94 2,661.14 -353.16 -517.52 5,981,956.99 258,312.35 0.45 616.09 2,854.80 30.45 235.54 2,719.89 2,680.09 -359.51 -526.71 5,981,950.93 258,302.96 1.18 627.06 13 3l8" 2,857.80 30.43 235.60 2,722.48 2,682.68 -360.37 -527.96 5,981,950.11 258,301.68 1.18 628.55 2,882.80 30.60 235.35 2,744.02 2,704.22 -367.57 -538.42 5,981,943.26 258,291.00 0.85 641.03 2,907.80 30.87 234.77 2,765.51 2,725.71 -374.88 -548.89 5,981,936.28 258,280.29 1.60 653.56 2,932.80 30.67 235.05 2,786.99 2,747.19 -382.24 -559.36 5,981,929.27 258,269.60 0.98 666.11 2,957.80 30.61 234.75 2,808.50 2,768.70 -389.56 -569.78 5,981,922.28 258,258.94 0.66 678.60 2,982.80 30.67 234.33 2,830.01 2,790.21 -396.95 -580.16 5,981,915.23 258,248.33 0.89 691.08 3,007.80 30.77 234.47 2,851.50 2,811.70 404.39 -590.54 5,981,908.13 258,237.72 0.49 703.59 3,032.80 30.68 234.40 2,872.99 2,833.19 -411.82 -600.93 5,981,901.04 258,227.09 0.39 716.09 3,057.80 30.86 234.07 2,894.47 2,854.67 -419.29 -611.31 5,981,893.90 258,216.48 0.99 728.61 3,082.80 31.68 233.37 2,915.84 2,876.04 -426.97 -621.77 5,981,886.57 258,205.78 3.59 741.28 3,107.80 32.55 233.49 2,937.01 2,897.21 -434.89 -632.45 5,981,879.00 258,194.86 3.49 754.24 3,132.80 33.01 232.79 2,958.03 2,918.23 -443.01 -643.28 5,981,871.23 258,183.77 2.38 767.43 3,157.80 33.48 232.44 2,978.94 2,939.14 451.33 -654.17 5,981,863.26 258,172.62 2.03 780.75 3,182.80 34.13 232.10 2,999.71 2,959.91 -459.84 -665.17 5,981,855.11 258,161.35 2.71 794.25 3,207.80 33.68 232.87 3,020.46 2,980.66 -468.34 -676.23 5,981,846.98 258,150.02 2.49 807.80 3,232.80 33.48 232.98 3,041.29 3,001.49 -476.67 -687.26 5,981,839.00 258,138.73 0.84 821.26 3,257.80 33.77 232.70 3,062.11 3,022.31 -485.03 -698.29 5,981,831.00 258,127.43 1.32 834.73 3,282.80 34.26 232.44 3,082.83 3,043.03 -493.53 -709.40 5,981,822.86 258,116.06 2.04 848.33 3,307.80 34.46 232.51 3,103.47 3,063.67 -502.13 -720.59 5,981,814.63 258,104.60 0.82 _ 862.03 7/18/2018 11:38:06AM Page 5 COMPASS 5000.1 Build 81E HALLIBURTON Halliburton Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Coordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC TVD Reference: DIU 2-66A wp03 IRKS @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 IRKS @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Design: 2-66A WP04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1 (usft) usft (usft) (usft) (usft) (usft) 3,084.29 3,332.80 34.35 232.96 3,124.09 3,084.29 -510.68 -731.83 5,981,806.44 258,093.09 1.11 875.77 3,357.80 34.15 232.85 3,144.76 3,104.96 -519.17 -743.05 5,981,798.32 258,081.60 0.84 889.47 3,382.80 34.36 232.90 3,165.42 3,125.62 -527.66 -754.27 5,981,790.20 258,070.11 0.85 903.16 3,407.80 34.33 232.73 3,186.06 3,146.26 -536.19 -765.51 5,981,782.04 258,058.61 0.40 916.89 3,432.80 34.59 233.18 3,206.68 3,166.88 -544.71 -776.80 5,981,773.89 258,047.05 1.46 930.66 3,457.80 35.17 233.06 3,227.18 3,187.38 -553.29 -788.24 5,981,765.68 258,035.34 2.34 944.58 3,482.80 35.59 233.39 3,247.57 3,207.77 -561.95 -799.83 5,981,757.39 258,023.47 1.85 958.69 3,507.80 36.48 233.67 3,267.78 3,227.98 -570.69 -811.66 5,981,749.03 258,011.37 3.62 973.04 3,532.80 36.83 233.75 3,287.84 3,248.04 -579.53 -823.69 5,981,740.59 257,999.07 1.41 987.62 3,557.80 37.60 233.16 3,307.75 3,267.95 -588.53 -835.83 5,981,731.98 257,986.64 3.39 1,002.36 3,582.80 38.16 233.45 3,327.48 3,287.68 -597.70 -848.14 5,981,723.21 257,974.04 2.35 1,017.33 3,607.80 38.58 234.11 3,347.08 3,307.28 -606.87 -860.66 5,981,714.45 257,961.23 2.35 1,032.49 3,632.80 39.23 233.37 3,366.54 3,326.74 -616.16 -873.32 5,981,705.58 257,948.28 3.20 1,047.82 3,657.80 39.64 233.43 3,385.84 3,346.04 -625.63 -886.07 5,981,696.53 257,935.23 1.65 1,063.31 3,682.80 39.79 233.37 3,405.08 3,365.28 -635.15 -898.89 5,981,687.42 257,922.11 0.62 1,078.89 3,707.80 40.10 233.20 3,424.24 3,384.44 -644.75 -911.76 5,981,678.24 257,908.94 1.31 1,094.53 3,732.80 40.33 233.16 3,443.33 3,403.53 -654.42 -924.68 5,981,668.99 257,895.71 0.93 1,110.26 3,757.80 40.70 232.87 3,462.34 3,422.54 -664.19 -937.66 5,981,659.64 257,882.43 1.66 1,126.08 3,782.80 41.66 232.43 3,481.15 3,441.35 -674.18 -950.74 5,981,650.08 257,869.04 4.01 1,142.08 3,807.80 42.14 232.10 3,499.76 3,459.96 -684.40 -963.94 5,981,640.30 257,855.51 2.11 1,158.29 3,832.80 42.75 231.46 3,518.21 3,478.41 -694.84 -977.20 5,981,630.29 257,841.93 2.99 1,174.63 3,857.80 43.92 231.05 3,536.39 3,496.59 -705.57 -990.58 5,981,619.99 257,828.21 4.81 1,191.21 3,882.80 44.82 230.68 3,554.26 3,514.46 -716.61 -1,004.14 5,981,609.40 257,814.30 3.75 1,208.07 3,907.80 45.26 230.24 3,571.93 3,532.13 -727.87 -1,017.78 5,981,598.58 257,800.30 2.16 1,225.10 3,932.80 46.19 229.74 3,589.38 3,549.58 -739.38 -1,031.49 5,981,587.52 257,786.23 3.99 1,242.29 3,957.80 47.34 229.39 3,606.51 3,566.71 -751.19 -1,045.35 5,981,576.16 257,772.00 4.71 1,259.74 3,982.80 47.80 229.44 3,623.37 3,583.57 -763.20 -1,059.37 5,981,564.61 257,757.60 1.85 1,277.41 4,007.80 48.16 229.47 3,640.11 3,600.31 -775.27 -1,073.48 5,981,553.00 257,743.11 1.44 1,295.20 4,032.80 48.12 229.81 3,656.79 3,616.99 -787.33 -1,087.67 5,981,541.40 257,728.54 1.03 1,313.05 4,057.80 48.20 230.06 3,673.47 3,633.67 -799.32 -1,101.92 5,981,529.88 257,713.91 0.81 1,330.93 4,082.80 47.89 230.37 3,690.18 3,650.38 -811.21 -1,116.21 5,981,518.45 257,699.25 1.55 1,348.81 4,107.80 47.76 230.52 3,706.97 3,667.17 -823.01 -1,130.49 5,981,507.12 257,684.59 0.68 1,366.64 4,132.80 47.65 230.84 3,723.79 3,683.99 -834.73 -1,144.80 5,981,495.87 257,669.92 1.04 1,384.46 4,157.80 47.46 231.08 3,740.66 3,700.86 -846.35 -1,159.13 5,981,484.72 257,655.22 1.04 1,402.27 4,182.80 47.38 231.43 3,757.58 3,717.78 -857.87 -1,173.49 5,981,473.66 257,640.50 1.08 1,420.05 4,207.80 47.51 231.81 3,774.49 3,734.69 -869.30 -1,187.92 5,981,462.70 257,625.70 1.23 1,437.88 4,232.80 47.59 232.16 3,791.36 3,751.56 -880.66 -1,202.46 5,981,451.81 257,610.81 1.08 1,455.76 4,257.80 47.83 232.26 3,808.18 3,768.38 -892.00 -1,217.07 5,981,440.96 257,595.84 1.00 1,473.71 4,282.80 48.10 232.37 3,824.92 3,785.12 -903.35 -1,231.76 5,981,430.09 257,580.79 1.13 1,491.74 4,307.80 48.71 232.42 3,841.52 3,801.72 -914.76 -1,246.58 5,981,419.16 257,565.62 2.44 1,509.90 4,332.80 49.65 232.27 3,857.86 3,818.06 -926.31 -1,261.55 5,981,408.09 257,550.28 3.79 1,528.27 4,357.80 50.16 232.31 3,873.96 3,834.16 -938.01 -1,276.68 5,981,396.89 257,534.78 2.04 1,546.84 4,382.80 50.79 232.42 3,889.87 3,850.07 -949.79 -1,291.96 5,981,385.61 257,519.14 2.54 1,565.56 4,407.80 51.48 232.21 3,905.56 3,865.76 -961.69 -1,307.36 5,981,374.21 257,503.36 2.84 1,584.46 4,432.80 51.74 232.26 3,921.08 3,881.28 -973.69 -1,322.85 5,981,362.72 257,487.49 1.05 1,603.48 7/16/2018 11:38:06AM Page 6 COMPASS 5000.1 Build 81E Planned Survey Measured Halliburton H A L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66Awp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Azimuth Depth Design: 2-66A WP04 TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +El -W Northing Easting DES Vert Section (usft) (1 (1) (usft) usft (usft) (usft) (usft) (usft) 3,896.75 4,457.80 51.83 232.27 3,936.55 3,896.75 -985.71 -1,338.38 5,981,351.20 257,471.58 0.36 1,622.55 4,482.80 51.81 232.34 3,952.00 3,912.20 -997.72 -1,353.93 5,981,339.69 257,455.65 0.23 1,641.63 4,507.80 51.77 232.35 3.967.47 3,927.67 -1,009.73 -1,369.49 5,981,328.20 257,439.72 0.16 1,660.70 4,532.80 51.84 232.44 3,982.92 3,943.12 -1,021.71 -1,385.05 5,981,316.72 257,423.78 0.40 1,679.78 4,557.80 51.81 232.40 3,998.38 3,958.58 -1,033.70 -1,400.63 5,981,305.24 257,407.83 0.17 1,698.87 4,582.80 51.62 232.48 4,013.87 3,974.07 -1,045.66 -1,416.18 5,981,293.79 257,391.89 0.80 1,717.94 4,607.80 51.70 232.62 4,029.37 3,989.57 -1,057.59 -1,431.75 5,981,282.37 257,375.95 0.54 1,736.99 4,632.80 51.13 233.07 4,044.97 4,005.17 -1,069.39 -1,447.33 5,981,271.07 257,360.00 2.68 1,756.01 4,657.80 50.80 232.83 4,060.71 4,020.91 -1,081.09 -1,462.82 5,981,259,88 257,344.14 1.52 1,774.91 4,682.80 50.50 232.24 4,076.56 4,036.76 -1,092.85 -1,478.17 5,981,248.62 257,328.42 2.18 1,793.70 4,707.80 50.23 231.96 4,092.51 4,052.71 -1,104.68 -1,493.36 5,981,237.29 257,312.86 1.38 1,812.38 4,732.80 50.70 232.00 4,108.42 4,068.62 -1,116.55 -1,508.55 5,981,225.91 257,297.30 1.88 1,831.07 4,757.80 50.64 231.86 4,124.27 4,084.47 -1,128.48 -1,523.77 5,981,214.48 257,281.70 0.50 1,849.81 4,782.80 50.74 231.71 4,140.11 4,100.31 -1,140.44 -1,538.97 5,981,203.01 257,266.12 0.61 1,868.55 4,807.80 50.97 231.64 4,155.89 4,116.09 -1,152.46 -1,554.18 5,981,191.48 257,250.53 0.95 1,887.32 4,832.80 51.27 231.47 4,171.58 4,131.78 -1,164.56 -1,569.42 5,981,179.88 257,234.91 1.31 1,906.15 4,857.80 51.15 231.46 4,187.24 4,147.44 -1,176.70 -1,584.67 5,981,168.24 257,219.28 0.48 1,925.00 4,882.80 50.50 231.60 4,203.03 4,163.23 -1,188.76 -1,599.84 5,981,156.68 257,203.73 2.64 1,943.75 4,907.80 50.22 231.66 4,218.98 4,179.18 -1,200.71 -1,614.93 5,981,145.22 257,188.26 1.14 1,962.39 4,932.80 50.22 231.75 4,234.98 4,195.18 -1,212.62 -1,630.01 5,981,133.80 257,172.81 0.28 1,980.99 4,957.80 50.24 231.74 4,250.97 4,211.17 -1,224.52 -1,645.10 5,981,122.40 257,157.34 0.09 1,999.60 4,982.80 50.14 231.81 4,266.98 4,227.18 -1,236.40 -1,660.19 5,981,111.01 257,141.88 0.45 2,018.20 5,007.80 50.34 231.90 4,282.97 4,243.17 -1,248.27 -1,675.30 5,981,099.63 257,126.40 0.85 2,036.83 5,032.80 50.35 231.96 4,298.92 4,259.12 -1,260.14 -1,690.46 5,981,088.26 257,110.87 0.19 2,055.48 5,057.80 50.19 232.14 4,314.90 4,275.10 -1,271.96 -1,705.62 5,981,076.93 257,095.34 0.85 2,074.13 5,082.80 49.94 232.21 4,330.95 4,291.15 -1,283.72 -1,720.76 5,981,065.67 257,079.82 1.02 2,092.73 5,107.80 49.40 232.32 4,347.13 4,307.33 -1,295.38 -1,735.83 5,981,054.49 257,064.39 2.19 2,111.23 5,132.80 49.55 232.30 4,363.37 4,323.57 -1,307.00 -1,750.87 5,981,043.37 257,048.98 0.60 2,129.68 5,157.80 49.88 232.44 4,379.54 4,339.74 -1,318.64 -1,765.97 5,981,032.21 257,033.51 1.39 2,148.20 5,182.80 50.05 232.37 4,395.62 4,355.82 -1,330.32 -1,781.14 5,981,021.03 257,017.98 0.71 2,166.79 5,207.80 50.42 232.45 4,411.61 4,371.81 -1,342.04 -1,796.37 5,981,009.81 257,002.38 1.50 2,185.46 5,232.80 50.54 232.44 4,427.52 4,387.72 -1,353.80 -1,811.65 5,980,998.55 256,986.72 0.48 2,204.19 5,257.80 50.42 232.56 4,443.43 4,403.63 -1,365.54 -1,826.95 5,980,987.31 256,971.05 0.61 2,222.93 5,282.80 49.66 232.79 4,459.48 4,419.68 -1,377.16 -1,842.19 5,980,976.19 256,955.45 3.12 2,241.56 5,307.80 49.26 233.07 4,475.73 4,435.93 -1,388.61 -1,857.35 5,980,965.23 256,939.93 1.81 2,260.06 5,332.80 49.39 233.13 4,492.03 4,452.23 -1,399.99 -1,872.51 5,980,954.34 256,924.41 0.55 2,278.53 5,357.80 49.42 233.26 4,508.29 4,468.49 -1,411.37 -1,887.71 5,980,943.46 256,908.85 0.41 2,297.02 5,382.80 49.27 233.26 4,524.58 4,484.78 -1,422.71 -1,902.91 5,980,932.61 256,893.30 0.60 2,315.51 5,407.80 49.68 233.29 4,540.83 4,501.03 -1,434.07 -1,918.14 5,980,921.74 256,877.71 1.64 2,334.03 5,432.80 49.65 233.26 4,557.01 4,517.21 -1,445.47 -1,933.42 5,980,910.85 256,862.08 0.15 2,352.61 5,457.80 49.59 233.22 4,573.20 4,533.40 -1,456.87 -1,948.67 5,980,899.95 256,846.46 0.27 2,371.17 5,482.80 49.63 233.27 4,589.40 4,549.60 -1,468.26 -1,963.93 5,980,889.05 256,830.85 0.22 2,389.73 5,507.80 49.57 233.07 4,605.61 4,565.81 -1,479.67 -1,979.17 5,980,878.13 256,815.25 0.65 2,408.28 5,532.80 50.06 232.52 4,621.74 4,581.94 -1,491.22 -1,994.38 5,980,867.08 256,799.67 2.58 2,426.86 5,557.80 50.04 231.55 4,637.79 4,597.99 -1,503.01 -2,009.49 5,980,855.78 256,784.19 2.98 2,445.45 7/182018 1138: 06AM Page 7 COMPASS 5000.1 Build 81E Planned Survey Halliburton H A L L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Design: 2-66A WP04 Vertical Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 4,614.03 5,582.80 50.15 231.02 4,653.83 4,614.03 -1,515.01 -2,024.45 5,980,844.28 256,768.85 1.68 2,463.98 5,607.80 50.01 230.92 4,669.87 4,630.07 -1,527.08 -2,039.35 5,980,832.69 256,753.58 0.64 2,482.48 5,632.80 50.03 231.00 4,685.94 4,646.14 -1,539.15 -2,054.23 5,980,821.11 256,738.32 0.26 2,500.97 5,657.80 50.25 230.96 4,701.96 4,662.16 -1,551.23 -2,069.14 5,980,809.51 256,723.03 0.89 2,519.49 5,682.80 50.23 231.03 4,717.95 4,678.15 -1,563.32 -2,084.07 5,980,797.91 256,707.71 0.23 2,538.04 5,707.80 50.14 231.24 4,733.95 4,694.15 -1,575.37 -2,099.02 5,980,786.34 256,692.38 0.74 2,556.58 5,732.80 50.33 231.24 4,749.95 4,710.15 -1,587.40 -2,114.01 5,980,774.80 256,677.02 0.76 2,575.15 5,757.80 50.58 231.20 4,765.86 4,726.06 -1,599.48 -2,129.04 5,980,763.22 256,661.61 1.01 2,593.78 5,782.80 50.62 231.12 4,781.73 4,741.93 -1,611.59 -2,144.08 5,980,751.59 256,646.18 0.29 2,612.44 5,807.80 50.48 231.22 4,797.62 4,757.82 -1,623.70 -2,159.12 5,980,739.98 256,630.76 0.64 2,631.08 5,832.80 50.42 231.21 4,813.54 4,773.74 -1,635.77 -2,174.15 5,980,728.40 256,615.35 0.24 2,649.71 5,857.80 49.91 231.47 4,829.55 4,789.75 -1,647.77 -2,189.14 5,980,716.89 256,599.99 2.19 2,668.27 5,882.80 49.35 231.61 4,845.74 4,805.94 -1,659.61 -2,204.05 5,980,705.53 256,584.70 2.28 2,686.70 5,907.80 49.64 231.64 4,861.98 4,822.18 -1,671.41 -2,218.95 5,980,694.22 256,569.43 1.16 2,705.10 5,932.80 49.86 231.69 4,878.13 4,838.33 -1,683.25 -2,233.92 5,980,682.87 256,554.09 0.89 2,723.57 5,957.80 50.08 231.73 4,894.21 4,854.41 -1,695.11 -2,248.95 5,980,671.50 256,538.69 0.89 2,742.10 5,982.80 49.81 231.91 4,910.30 4,870.50 -1,706.94 -2,263.99 5,980,660.16 256,523.27 1.21 2,760.64 6,007.80 49.53 232.01 4,926.48 4,886.68 -1,718.68 -2,279.00 5,980,648.91 256,507.89 1.16 2,779.12 6,032.80 49.58 231.88 4,942.70 4,902.90 -1,730.41 -2,293.98 5,980,637.67 256,492.54 0.44 2,797.56 6,057.80 49.35 231.89 4,958.95 4,919.15 -1,742.14 -2,308.93 5,980,626.43 256,477.23 0.92 2,815.97 6,082.80 49.21 231.86 4,975.26 4,935.46 -1,753.84 -2,323.83 5,980,615.22 256,461.95 0.57 2,834.34 6,107.80 49.13 231.77 4,991.60 4,951.80 -1,765.53 -2,338.70 5,980,604.01 256,446.71 0.42 2,852.66 6,132.80 48.84 231.79 5,008.01 4,968.21 -1,777.20 -2,353.52 5,980,592.82 256,431.53 1.16 2,870.93 6,157.80 48.87 231.67 5,024.46 4,984.66 -1,788.86 -2,368.30 5,980,581.64 256,416.38 0.38 2,889.16 6,182.80 48.74 231.64 5,040.92 5,001.12 -1,800.53 -2,383.06 5,980,570.45 256,401.26 0.53 2,907.38 6,207.80 48.64 231.63 5,057.43 5,017.63 -1,812.19 -2,397.78 5,980,559.28 256,386.17 0.40 2,925.55 6,232.80 48.53 231.58 5,073.96 5,034.16 -1,823.83 -2,412.47 5,980,548.11 256,371.11 0.46 2,943.70 6,257.80 48.57 231.63 5,090.51 5,050.71 -1,835.47 -2,427.16 5,980,536.95 256,356.05 0.22 2,961.84 6,282.80 48.45 231.66 5,107.07 5,067.27 -1,847.09 -2,441.85 5,980,525.81 256,341.00 0.49 2,979.96 6,307.80 48.53 231.63 5,123.64 5,083.84 -1,858.71 -2,456.53 5,980,514.67 256,325.96 0.33 2,998.09 6,332.80 48.24 231.63 5,140.25 5,100.45 -1,870.31 -2,471.18 5,980,503.55 256,310.94 1.16 3,016.18 6,357.80 48.24 231.59 5,156.90 5,117.10 -1,881.89 -2,485.80 5,980,492.45 256,295.96 0.12 3,034.23 6,382.80 48.23 231.55 5,173.55 5,133.75 -1,893.48 -2,500.40 5,980,481.33 256,280.98 0.13 3,052.27 6,407.80 48.05 231.51 5,190.23 5,150.43 -1,905.06 -2,514.98 5,980,470.22 256,266.04 0.73 3,070.29 6,432.80 48.10 231 sit 5,206.94 5,167.14 -1,916.62 -2,529.56 5,980,459.15 256,251.10 0.54 3,088.29 6,457.80 48.02 231.65 5,223.64 5,183.84 -1,928.15 -2,544.14 5,980,448.09 256,236.15 0.33 3,106.30 6,482.80 47.93 231.74 5,240.38 5,200.58 -1,939.66 -2,558.72 5,980,437.05 256,221.22 0.45 3,124.28 6,507.80 47.96 231.79 5,257.13 5,217.33 -1,951.15 -2,573.30 5,980,426.04 256,206.27 0.19 3,142.26 6,532.80 48.25 231.74 5,273.82 5,234.02 -1,962.67 -2,587.92 5,980,415.00 256,191.29 1.17 3,160.28 6,557.80 48.17 231.85 5,290.48 5,250.68 -1,974.20 -2,602.56 5,980,403.95 256,176.28 0.46 3,178.34 6,582.80 48.60 231.87 5,307.08 5,267.28 -1,985.74 -2,617.26 5,980,392.88 256,161.22 1.72 3,196.45 6,607.80 48.42 231.83 5,323.65 5,283.85 -1,997.31 -2,631.99 5,980,381.80 256,146.13 0.73 3,214.59 6,632.80 48.28 231.74 5,340.26 5,300.46 -2,008.86 -2,646.67 5,980,370.72 256,131.09 0.62 3,232.69 6,657.80 48.30 231.65 5,356.89 5,317.09 -2,020.43 -2,661.31 5,980,359.63 256,116.08 0.28 3,250.76 6,682.80 48.32 231.63 5,373.52 5,333.72 -2,032.02 -2,675.95 5,980,348.52 256,101.07 0.10 3,268.83 7/182018 11:38.06AM Page 8 COMPASS 5000.1 Build 81E HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Duck Island Unit Site: End MPI Well: Plan: DIU 2-66A Wellbore: Plan: 2-66A Design: 2-66A WP04 Planned Survey Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: DIU 2-66A TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) North Reference: True Survey Calculation Method: Minimum Curvature Measured 255,574.33 Map Vertical 5,979,896.65 255,518.43 4.00 Depth Inclination Azimuth Depth TVDss +NIS +EI -W (usft) (1) (1 (usft) usft (usft) (usft) 6,707.80 48.36 231.60 5,390.14 5,350.34 -2,043.62 -2,690.59 6,732.80 47.93 231.49 5,406.82 5,367.02 -2,055.20 -2,705.17 6,757.80 48.01 231.33 5,423.56 5,383.76 -2,066.78 -2,719.69 6,782.80 48.18 231.22 5,440.26 5,400.46 -2,078.42 -2,734.20 6,807.80 48.11 231.10 5,456.94 5,417.14 -2,090.10 -2,748.71 6,832.80 47.88 230.87 5,473.67 5,433.87 -2,101.79 -2,763.14 6,857.80 47.80 230.75 5,490.45 5,450.65 -2,113.50 -2,777.50 6,882.80 47.66 230.59 5,507.26 5,467.46 -2,125.23 -2,791.81 6,907.80 47.43 230.46 5,524.14 5,484.34 -2,136.95 -2,806.05 6,932.80 48.16 230.35 5,540.93 5,501.13 -2,148.76 -2,820.32 6,957.80 47.57 230.25 5,557.71 5,517.91 -2,160.60 -2,834.59 6,982.80 47.60 230.12 5,574.57 5,534.77 -2,172.42 -2,848.76 7,007.80 47.53 229.96 5,591.44 5,551.64 -2,184.27 -2,862.91 7,032.80 47.40 229.86 5,608.34 5,568.54 -2,196.13 -2,877.00 7,057.80 47.19 229.68 5,625.29 5,585.49 -2,208.00 -2,891.02 7,082.80 47.09 229.58 5,642.30 5,602.50 -2,219.86 -2,904.99 7,107.80 46.95 229.47 5,659.34 5,619.54 -2,231.74 -2,918.90 7,132.80 46.92 229.33 5,676.41 5,636.61 -2,243.62 -2,932.77 7,157.80 46.65 229.24 5,693.53 5,653.73 -2,255.51 -2,946.58 7,182.80 46.38 229.17 5,710.74 5,670.94 -2,267.36 -2,960.31 7,207.80 46.00 229.21 5,728.04 5,688.24 -2,279.15 -2,973.96 7,232.80 46.26 229.08 5,745.37 5,705.57 -2,290.94 -2,987.60 7,257.80 46.58 229.17 5,762.60 5,722.80 -2,302.79 -3,001.29 7,282.80 46.56 229.28 5,779.79 5,739.99 -2,314.65 -3,015.04 7,307.80 46.34 229.20 5,797.01 5,757.21 -2,326.48 -3,028.76 7,332.80 45.69 229.27 5,814.37 5,774.57 -2,338.22 -3,042.39 7,357.80 46.31 229.18 5,831.74 5,791.94 -2,349.97 -3,056.01 7,382.80 46.04 229.07 5,849.05 5,809.25 -2,361.77 -3,069.64 7,407.80 45.94 228.86 5,866.42 5,826.62 -2,373.58 -3,083.21 7,432.80 45.75 228.89 5,883.84 5,844.04 -2,385.37 -3,096.72 7,457.80 45.72 228.73 5,901.29 5,861.49 -2,397.16 -3,110.19 7,482.80 45.68 228.51 5,918.75 5,878.95 -2,408.99 -3,123.62 7,500.00 45.62 228.86 5,930.77 5,890.97 -2,417.11 -3,132.85 KOP : Start Dir 12.29-/100': 7500' MD, 5930.77'TVD, 60' RT TF - 9 518" TOW 7,517.00 46.67 231.37 5,942.55 5,902.75 -2,424.97 -3,142.26 End Dir : 7517' MD, 5942.55' TVD 0.00 3,875.25 7,547.00 46.67 231.37 5,963.14 5,923.34 -2,438.59 -3,159.31 Start Dir 4-1100': 7547' MD, 5963.14'TVD 7,600.00 44.69 232.43 6,000.17 5,960.37 -2,461.99 -3,189.14 7,700.00 40.98 234.64 6,073.49 6,033.69 -2,502.42 -3,243.77 7,800.00 37.32 237.21 6,151.03 6,111.23 -2,537.83 -3,296.02 7,900.00 33.73 240.25 6,232.41 6,192.61 -2,568.03 -3,345.63 8,000.00 30.23 243.91 6,317.22 6,277.42 -2,592.89 -3,392.37 8,100.00 26.86 248.41 6,405.06 6,365.26 -2,612.29 -3,436.00 8,200.00 23.66 254.05 6,495.51 6,455.71 -2,626.12 -3,476.31 Map 255,574.33 Map 3,911.99 5,979,896.65 255,518.43 4.00 Northing 5,979,862.95 Easting 4.00 DLS Vert Section (usft) 4.00 (usft) 5,979,811.01 5,350.34 4.00 4,150.79 5,980,337.40 255,322.77 256,086.07 4,198.53 0.18 3,286.91 4.00 5,980,326.30 256,071.12 1.75 3,304.93 5,980,315.19 256,056.24 0.57 3,322.88 5,980,304.02 256,041.36 0.75 3,340.86 5,980,292.82 256,026.49 0.45 3,358.85 5,980,281.59 256,011.69 1.15 3,376.78 5,980,270.35 255,996.95 0.48 3,394.65 5,980,259.09 255,982.27 0.73 3,412.48 5,980,247.83 255,967.67 1.00 3,430.24 5,980,236.49 255,953.03 2.94 3,448.06 5,980,225.12 255,938.39 2.38 3,465.89 5,980,213.76 255,923.84 0.40 3,483.64 5,980,202.37 255,909.32 0.55 3,501.36 5,980,190.97 255,894.86 0.60 3,519.05 5,980,179.56 255,880.46 0.99 3,536.67 5,980,168.15 255,866.12 0.50 3,554.24 5,980,156.73 255,851.83 0.65 3,571.76 5,980,145.30 255,837.59 0.43 3,589.25 5,980,133.86 255,823.40 1.11 3,606.68 5,980,122.46 255,809.30 1.10 3,624.03 5,980,111.12 255,795.27 1.52 3,641.29 5,980,099.77 255,781.27 1.11 3,658.52 5,980,088.37 255,767.20 1.31 3,675.84 5,980,076.96 255,753.08 0.33 3,693.20 5,980,065.58 255,738.98 0.91 3,710.54 5,980,054.28 255,724.99 2.61 3,727.75 5,980,042.98 255,711.00 2.49 3,744.95 5,980,031.62 255,696.99 1.13 3,762.19 5,980,020.26 255,683.05 0.72 3,779.37 5,980,008.90 255,669.17 0.76 3,796.49 5,979,997.55 255,655.32 0.47 3,813.58 5,979,986.17 255,641.52 0.65 3,830.64 5,979,978.35 255,632.03 1.50 3,842.37 5,979,970.80 255,622.38 12.29 3,854.15 5,979,957.73 255,604.90 0.00 3,875.25 5,979,935.30 255,574.33 4.00 3,911.99 5,979,896.65 255,518.43 4.00 3,978.30 5,979,862.95 255,465.07 4.00 4,040.40 5,979,834.36 255,414.51 4.00 4,097.99 5,979,811.01 255,367.00 4.00 4,150.79 5,979,793.04 255,322.77 4.00 4,198.53 5,979,780.51 255,282.04 4.00 4,240.99 7/182018 11:38:06AM Page 9 COMPASS 5000.1 Build 81E Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: DIU 2-66A Company: Hilcorp Alaska, LLC ND Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Design: 2-66A WP04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (1 (1) (usft) usft (usft) (usft) (usft) (usft) 6,548.31 8,300.00 20.72 261.27 6,588.11 6,548.31 -2,634.32 -3,513.10 5,979,773.50 255,245.00 4.00 4,277.97 8,400.00 18.18 270.56 6,682.41 6,642.61 -2,636.85 -3,546.20 5,979,772.03 255,211.84 4.00 4,309.27 8,500.00 16.21 282.38 6,777.97 6,738.17 -2,633.71 -3,575.45 5,979,776.12 255,182.71 4.00 4,334.75 8,600.00 15.04 296.63 6,874.31 6,834.51 -2,624.89 -3,600.69 5,979,785.74 255,157.76 4.00 4,354.28 8,700.00 14.87 312.15 6,970.96 6,931.16 -2,610.46 -3,621.82 5,979,800.84 255,137.11 4.00 4,367.77 8,800.00 15.73 327.01 7,067.45 7,027.65 -2,590.47 -3,638.72 5,979,821.37 255,120.86 4.00 4,375.15 8,817.12 15.97 329.36 7,083.92 7,044.12 -2,586.50 -3,641.18 5,979,825.41 255,118.53 4.00 4,375.80 End Dir : 8817.12' MD, 7083.92' TVD 8,900.00 15.97 329.36 7,163.60 7,123.80 -2,566.88 -3,652.80 5,979,845.39 255,107.54 0.00 4,378.51 9,000.00 15.97 329.36 7,259.74 7,219.94 -2,543.21 -3,666.83 5,979,869.50 255,094.29 0.00 4,381.77 9,100.00 15.97 329.36 7,355.89 7,316.09 -2,519.55 -3,680.85 5,979,893.60 255,081.04 0.00 4,385.03 9,200.00 15.97 329.36 7,452.03 7,412.23 -2,495.88 -3,694.87 5,979,917.71 255,067.79 0.00 4,388.29 9,300.00 15.97 329.36 7,548.17 7,508.37 -2,472.21 -3,708.89 5,979,941.82 255,054.54 0.00 4,391.56 9,400.00 15.97 329.36 7,644.31 7,604.51 -2,448.55 -3,722.91 5,979,965.92 255,041.29 0.00 4,394.82 9,500.00 15.97 329.36 7,740.45 7,700.65 -2,424.88 -3,736.93 5,979,990.03 255,028.04 0.00 4,398.08 9,600.00 15.97 329.36 7,836.59 7,796.79 -2,401.21 -3,750.95 5,980,014.13 255,014.78 0.00 4,401.35 9,700.00 15.97 329.36 7,932.74 7,892.94 -2,377.54 -3,764.97 5,980,038.24 255,001.53 0.00 4,404.61 9,800.00 15.97 329.36 8,028.88 7,989.08 -2,353.88 -3,778.99 5,980,062.34 254,988.28 0.00 4,407.87 9,900.00 15.97 329.36 8,125.02 8,085.22 -2,330.21 -3,793.02 5,980,086.45 254,975.03 0.00 4,411.13 10,000.00 15.97 329.36 8,221.16 8,181.36 -2,306.54 -3,807-04 5,980,110.55 254,961.78 0.00 4,414.40 10,100.00 15.97 329.36 8,317.30 8,277.50 -2,282.87 -3,821.06 5,980,134.66 254,948-53 0.00 4,417.66 10,200.00 15.97 329.36 8,413.45 8,373.65 -2,259.21 -3,835.08 5,980,158.76 254,935.27 0.00 4,420.92 10,300.00 15.97 329.36 8,509.59 8,469.79 -2,235.54 -3,849.10 5,980,182.87 254,922.02 0.00 4,424.19 10,400.00 15.97 329.36 8,605.73 8,565.93 -2,211.87 -3,863.12 5,980,206.98 254,908.77 0.00 4,427.45 10,500.00 15.97 329.36 8,701.87 8,662.07 -2,188.21 -3,877.14 5,980,231.08 254,895.52 0.00 4,430.71 10,600.00 15.97 329.36 8,798.01 8,758.21 -2,164.54 -3,891.16 5,980,255.19 254,882.27 0.00 4,433.97 10,611.22 15.97 329.36 8,808.80 8,769.00 -2,161.88 -3,892.74 5,980,257.89 254,880.78 0.00 4,434.34 TUFF 10,700.00 15.97 329.36 8,894.16 8,854.36 -2,140.87 -3,905.18 5,980,279.29 254,869.02 0.00 4,437.24 10,800.00 15.97 329.36 8,990.30 8,950.50 -2,117.20 -3,919.21 5,980,303.40 254,855.76 0.00 4,440.50 10,900.00 15.97 329.36 9,086.44 9,046.64 -2,093.54 -3,933.23 5,980,327.50 254,842.51 0.00 4,443.76 11,000.00 15.97 329.36 9,182.58 9,142.78 -2,069.87 -3,947.25 5,980,351.61 254,829.26 0.00 4,447.02 11,065.75 15.97 329.36 9,245.80 9,206.00 -2,054.31 -3,956.47 5,980,367.46 254,820.55 0.00 4,449.17 THRZ 11,100.00 15.97 329.36 9,278.72 9,238.92 -2,046.20 -3,961.27 5,980,375.71 254,816.01 0.00 4,450.29 11,200.00 15.97 329.36 9,374.87 9,335.07 -2,022.54 -3,975.29 5,980,399.82 254,802.76 0.00 4,453.55 11,226.97 15.97 329.36 9,400.80 9,361.00 -2,016.15 -3,979.07 5,980,406.32 254,799.18 0.00 4,454.43 LCU - TITK 11,300.00 15.97 329.36 9,471.01 9,431.21 -1,998.87 -3,989.31 5,980,423.92 254,789.51 0.00 4,456.81 11,400.00 15.97 329.36 9,567.15 9,527.35 -1,975.20 -4,003.33 5,980,448.03 254,776.26 0.00 4,460.08 11,500.00 15.97 329.36 9,663.29 9,623.49 -1,951.53 -4,017.35 5,980,472.14 254,763.00 0.00 4,463.34 11,600.00 15.97 329.36 9,759.43 9,719.63 -1,927.87 4,031.37 5,980,496.24 254,749.75 0.00 4,466.60 11,700.00 15.97 329.36 9,855.58 9,815.78 -1,904.20 -4,045.39 5,980,520.35 254,736.50 0.00 4,469.86 11,800.00 15.97 329.36 9,951.72 9,911.92 -1,880.53 4,059.42 5,980,544.45 254,723.25 0.00 4,473.13 7/182018 11:38:06AM Page 10 COMPASS 5000.1 Build 81E HALLIBURTON Halliburton Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well Plan: DIU 2-66A Company: Hiloorp Alaska, LLC TVD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Project: Duck Island Unit MD Reference: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Site: End MPI North Reference: True Well: Plan: DIU 2-66A Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2-66A Measured Vertical Casing Hole Design: 2-66A WP04 Diameter Diameter (usft) (usft) Name Planned Survey 9-5/8 12-1/4 12,092.78 10,233.20 7"x81/2" 7 8-1/2 Measured Vertical Measured Vertical Vertical Map Map Dip Depth Inclination Azimuth Depth TVDss +NIS +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,950.00 11,839.61 15.97 329.36 9,989.80 9,950.00 -1,871.16 -4,064.97 5,980,554.00 254,718.00 0.00 4,474.42 FV TUFF Plan Annotations 11,900.00 15.97 329.36 10,047.86 10,008.06 -1,856.86 4,073.44 5,980,568.56 254,710.00 0.00 4,476.39 12,000.00 15.97 329.36 10,144.00 10,104.20 -1,833.20 4,087.46 5,980,592.66 254,696.75 0.00 4,479.65 12,092.78 • 15.97 329.36 10,233.20 .10,193.40 7,547.00 5,963.14 -2,438.59 -1,811.24 -4,100.47 5,980,615.03 254,684.45• 0.00 4,482.68 Total Depth : 12092.78' MD, 10233.2' TVD 12,092.78 10,23320 -1,811.24 -4,100.47 Total Depth : 12092.78' MD, 10233.2' TVD Targets 7/1812018 11:38.06AM Page 11 COMPASS 5000.1 Build 81E Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting - Shape (°) (°) (usft) (usft) (usft) (usft) (usft) MPI 2-66A Tgt 0.00 0.00 9,989.80 -1,871.16 -4,064.97 5,980,554.00 254,718.00 - plan hits target center - Circle (radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 7,500.00 5,930.77 95/8"TOW 9-5/8 12-1/4 12,092.78 10,233.20 7"x81/2" 7 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology 11,065.75 9,245.80 THRZ 11,226.97 9,400.80 TITK 11,226.97 9,400.80 LCU 11,839.61 9,989.80 FV 10,611.22 8,808.80 TUFF Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/,S +E/ -W (usft) (usft) (usft) (usft) Comment 7,500.00 5.930.77 -2,417.11 -3,132.85 KOP : Start Dir 12,29'/100': 7500' MD, 5930.77'TVD, 60° RT TF 7,517.00 5,942.55 -2,424.97 -3,142.26 End Dir : 7517' MD, 5942.55' TVD 7,547.00 5,963.14 -2,438.59 -3,159.31 Start Dir 4°/100' : 7547' MD, 5963.14'TVD 8,817.12 7,083.92 -2,586.50 -3,641.18 End Dir : 8817.12' MD, 7083.92' TVD 12,092.78 10,23320 -1,811.24 -4,100.47 Total Depth : 12092.78' MD, 10233.2' TVD 7/1812018 11:38.06AM Page 11 COMPASS 5000.1 Build 81E Hilcorp Alaska, LLC Duck Island Unit End MPI Plan: DIU 2-66A Plan: 2-66A 2-66A WP04 Sperry Drilling Services Clearance Summary Anticollision Report 18 July, 2018 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: End MPI - Plan: DIU 2-66A - Plan: 2-66A - 2-66A WP04 Well Coordinates: 5,982,293.29 N, 258,840.95E (70° 21' 08.10" N, 147° 57' 30.21" W) Datum Height: DIU 2-66A wp03 RKB @ 39.80usft (Innovation) Scan Range: 7,482.80 to 12,092.78 usft. Measured Depth. Scan Radius is 1,500.00 usft . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 81E Scan Type: • •' - Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: DIU 2-66A - 2-66A WP04 Hilcorp Alaska, LLC Duck Island Unit Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: End MPI - Plan: DIU 2.66A - Plan: 2-66A - 2.66A WP04 Scan Range: 7,482.80 to 12,092.78 usft. Measured Depth. Scan Radius is 1,500.00 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 End MPI 2-52 - 2-52 - 2-52 12,092.78 Survey Tool 1,100.50 (usft) 12,092.78 32.80 576.75 2_Gyro-NS-CT_Csg+Cent 11,880.46 2.101 Clearance Factor Pass - 2-60 - 2-60 - 2-60 10,182.80 1,017.30 10,182.80 912.29 9,961.12 9.688 Clearance Factor Pass - 2-60 - 2-60 - 2-60 10,184.75 1,017.30 10,184.75 912.29 9,962.59 9.688 Centre Distance Pass - 2-70 - 2-70 - 2-70 10,573.72 972.75 10,573.72 562.52 10,382.98 2.371 Centre Distance Pass - 2-70 - 2-70 - 2-70 10,932.80 992.69 10,932.80 538.07 10,698.23 2.184 Ellipse Separation Pass - 2-70-2-70-2-70 11,157.80 1,021.14 11,157.80 547.38 10,900.34 2.155 Clearance Factor Pass - Plan* DIU 2-66A-2-66-2-66 7,782.80 20.11 7,782.80 16.96 7,797.79 6.378 Clearance Factor Pass - Plan: DIU 2-66A - 2-66 PB1 - 2-66 PBI 7,782.80 20.11 7,782.80 16.80 7,797.79 6.078 Clearance Factor Pass - From To Survey/Plan Survey Tool (usft) (usft) 32.80 7,482.80 2_Gyro-NS-CT_Csg+Cent 7,482.80 7,880.00 2-66A WP04 2_MWD Interp Azi+Sag 7,880.00 12,092.78 2-66A WP04 2_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. 18 July, 2018 - 11:29 Page 2 of 4 COMPASS REFERENCE INFORMATION WE] DETAILS: Plan: DN 2-66A NAD 1927(NADCON COWS) Alaska Zone 03 HALLIBURTON Project: Duck Island Unit Site: End MPI CooNinme(Nq Refemnca. Well Plan: DIU"' Tme Nonh Ground Level: 1330 Vantin DVD)Reference: DIU 2-66A "a RKB 099nUsfl (Innovation) +N/-$ +F✓ -W Nonhin8 Eastin9 Tatinade Longitude Sperry Drilling Well: Plan: DIU 2-66A Meanund Depnh RMemroe:DIU2-WAwpaa R-0®.0uau(Innovalion) 0,00 000 5982293.29 258840.95 7W21'8.101N 147°57'30215W Wellbore: Plan: 2-66A calcu'aaon MNhW Minimum Dunztum Plan: 2-66A WPO4 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 10011000 of reference 7482.80 To 12092.78 1 SURVEY PROGRAM DETAILS FLadder/S.F.PlotsCASING Depth From Depth To Survey/Plan Tool TVD TVDSS MD Size Name 32.80 7482.80 286 Gyatata CT Rate Gym (286 Pal) 2 Gyro-NS-CT—Csg+Cent 5930.77 589097 7500.00 9-5/8 95/8"TOW 7462.80 7880.00 2-66AWP04(Plan: 286A) 2 MWD—Interp Azi+Sag 10233.20 10193.40 12092.78 7 7"x8IC" 7880.00 12092.78 2-66AWP04(Plan: 2 -WA) 2_MWD+IFR2+MS+Sag 200.00-- 00.00 F c m 0160.00 0 O W c g120.00 -- M `m n d N 80.00 c d U _ 2-6 40.00 2-66 B1 C N U 0.00 7200 7500 7800 8100 6400 8700 9000 9300 9600 9900 10200 10500 10800 11100 11400 11700 12000 12300 12600 Measured Depth (600 usftfin) 4.50 `o m 3.00 tl Collision Risk Procedures Req. 2_70 _ 0 2-52 VCollision Avoidance Req. I U) 1s0 ---- _ No -Go Zone -Stop Drilling 0.00 7000 7350 7700 8050 8400 8750 9100 9450 9800 10150 10500 10850 11200 11550 11900 12250 12600 Measured Depth (600 usft/in) TRANSMITTAL LETTER CHECKLIST WELL NAME: 1! Z !L M PZ �L= (,'g_ 06__ PTD: '� I$ -106' VDevelopment _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: FEN d i cc t't– POOL: I=—h a i C'0 -t -t- 0 t 1 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 shouiu �ontrnue to be reported as a function of the v,.ginai 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: Mihim4w,, LWA GR– Res required Well Logging brow, KO P to T. D - Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool ENDICOTT, ENDICOTT OIL - 220100_ _ Well Name: PUCK JS UNIT MPI _2-66&--- Program DEV _ _--_ Well bore seg ❑ PTD#:2181060 Company HILCORP ALASKA Lt�C Initial Classlrype DEV / PEND GeoArea 690_ _ — Unit _1.0450 On/Off Shore Off Annular Discosal Appr Date DLB 8/24/2018 Engineering Appr Date MGR 8/29/2018 '1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 Geology 36 Appr Date 37 DLB 8/24/2018 38 Nonconven. gas conforms to AS31,05.03001.A),(y2.A-D) .. _ _ _ _ _ _ _ _ _ .. NA Engineering Commissioner: Date �9� rp Permit fee attached _ _ NA Lease number appropriate. _ _ _ _ _ _ _ _ _ _ _ ... .. _ _ _ Yes Unique well. name and number _ _ _ _ _ _ _ _ _ _ _ ... Yes _ Well located in a. defined pool .. _ _ _ _ _ Yes Well located proper distance from drilling unit boundary. _ _ .. Yes Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ Yes Sufficient acreage. available in. drilling unit_ _ _ _ _ Yes _ If deviated, is wellbore plat included _ _ .. _ _ _ _ _ _ _ _ _ _ Yes Operator only affected party.......... _ _ _ _ _ Yes Operator has. appropriate bond in force _ _ _ _ ..... .. _ _ _ Yes Permit can be issued without conservation order... _ _ _ ..... Yes Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ _ --- Yes ----- ----- Can permit permit be approved before 15 day wad. ..... _ _ _ _ .. Yes Well located within area and strata authorized by Injection Order # (put. IO# in. comments). (For..NA All wells within 114. mile.area_of review identified (For service well only) ........ . . . . . . . NA .. _ ... _ .. . Pre -produced injector. duration of pre production less than 3 months (For service well only) _ , NA_ _ _ Conductor string_ provided _ _ _ _ _ _ _ _ _ _ _ _ _ ........ NA _ _ _ _ _ _ _ Not applicable, sidetrack out of 9-5/8" intermediate casing. Surface casing. protects all. known USDWs .............. . _ _ .... _ _ NA _ _ _ _ Not applicable, sidetrack out of 9-5/8" intermediate casing. _ _ _ ........... CMT. vol adequate to circulate_on conductor & surf csg _ _ _ ............. . . . . NA _ _ _ _ _ _ . Not applicable, sidetrack out of g-5/8". intermediate casing. _ CMT vol adequate to tie-in long string to surf csg- - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA...... CMT will coverall known productive horizons. _ ... _ _ _ _ _ _ _ .... Yes _ _ _ _ _ _ _ _ _ _ _ . Casing designs adequate for C, T, B.& permafrost _ _ _ . .. .. . . . . . . _ Yes Adequate tankage or reserve pit ..... _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ ........... If_a. re -drill, has_a 10-403 for abandonment been approved ..... . .... . . . . _ _ Yes Adequate wellbore separation proposed_ _ ___ _ _ _ _ _ _ _ _ _ _ _ Yes If diverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ ... Not applicable, sidetrack out of 9-5/8" intermediate casing Drilling Fluid program schematic .& equip list adequate... _ _ _ _ _ Yes _ __ BOPEs,.do they meet. regulation . . . . . . . . . ..... . ..... _ _ _ _ _ _ Yes BOPE_press rating appropriate: test to.(put psig in comments)_ _ _ . .. Yes Choke. manifold complies w/API. RP -53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ .. Yes . ..... . ...... . . . . . . . . .. Work will occur without operation shutdown. _ _ .. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Is presence of H2S gas. probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ Yes . Mechanical condition of wells within AOR verified (For service well only) _ _ .. _ ..... _ NA _ _ _ _ _ Well is oproducer._ .... _ .. _ . Permit can be issued w/o hydrogen sulfide measures _ ....... ... _ .. _ No.. _ _ Endicott Pool wells are H2S-bearing, F12S.measures are required__ Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ....... Planned drilling mud program (about 9.5 to 10,3 ppg) appears adequate to control operator's forecast Seismic analysis of shallow gas zones . . . . ........ .. . . _ _ _ _ _ . NA.... _ _ pore pressure_ gradient. Pending. hole stability, MW maybe increased. at TO up to 10,8. ppg.. Seabed condition survey.(if Off -shore) _ . NA Contact name/phone for weekly progress reports. [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA... Geologic Commissioner: PrIs Date: �wly Engineering Commissioner: Date �9� rp Public Commi er Date {J`�NS� i 6
