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217-026
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 March 26, 2024 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit M-28RD PTD 2170260 Dear Mr. Marlowe: On February 16, 2024, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit M-28RD located on the Steelhead Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 10-004. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated 2 additional times. There was neither gas nor oil flow rates observed during the no-flow test. Trading Bay Unit M- 28RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit M-28RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Steelhead Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2024.03.26 13:17:35 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT M-28RD JBR 04/12/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 Tested w 2 7/8" test joint. 2 7/8 x 5 1/2" VBR's failed and were changed out to 2 7/8 hard body rams. 3" demco on end of kill failed and was rebuilt. HCR choke failed and was replaced. All passing re-tests. Test Results TEST DATA Rig Rep:N.MitchellOperator:Hilcorp Alaska, LLC Operator Rep:Sloan Sunderland Rig Owner/Rig No.:Hilcorp 51 PTD#:2170260 DATE:3/10/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopAGE240313205322 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 22 MASP: 1237 Sundry No: 324-083 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8 X 5 1/2"P #2 Rams 1 Blind P #3 Rams 1 2 7/8"FP #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"FP Kill Line Valves 2 3 1/8"FP Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1450 200 PSI Attained P34 Full Pressure Attained P220 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P8@2300 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P11 #2 Rams P11 #3 Rams P11 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P5 HCR Kill P5 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: _________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,636 feet N/A feet true vertical 9,889 feet N/A feet Effective Depth measured 13,558 feet N/A feet true vertical 9,878 feet N/A feet Perforation depth Measured depth 11,842 - 13,290 feet True Vertical depth 9,647 - 9,846 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 11,654 (MD) 9,600 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:West Foreland Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3,220psi 4,760psi 2,630psi 3,090psi 5,860psi 6,870psi 4,590 4,027 Burst Collapse 1,020psi 1,540psi measured TVD Production Liner 497 8,052 5,226 Casing Conductor 497 7,051 7" 497 8,549 13,636 9,889 1,447 4,590 1,447Surface Intermediate Production 26" 16" 13-3/8" 10-3/4" 8,160psi 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-026 50-733-20414-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017594 / ADL0018730 McArthur River / Hemlock Oil & West Foreland Oil Trading Bay Unit M-28RD Plugs Junk measured Length 990 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 39 Gas-Mcf MD 990 N/A 76 Size 990 1,444 574 4830 40 185340 76 324-083 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 36 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:40 pm, Mar 27, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.03.27 11:17:32 - 08'00' Dan Marlowe (1267) RBDMS JSB 040224 DSR-4/12/24 Updated by: JLL 03/15/2024 SCHEMATIC McArthur River Field Steelhead Platform Well: M-28RD PTD: 217-026 API: 50-733-20414-01 Last Completed: 03/14/2024 CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 26” 267/397 Dril-Quip Surf 990’ 16” 75 K-55 Buttress 15.124” Surf 1,447’ 13-3/8”61 K-55 Buttress 12.515” Surf 2,563’ 68 K-55 Buttress 12.415” 2,563’ 4,590’ 10-3/4”51 N-80 Buttress 9.850” Surf 368’ 55.5 N-80 Buttress 9.760” 368’ 497’ 9-5/8”47 N-80 Buttress 8.681” 497’ 5,289’ 47 S-95 Buttress 8.681” 5,289’ 8,549’ (TOW) 7” 29 L-80 DWC/C 6.184” 8,300’ 13,636’ Tubing Detail 2-7/8” 6.4 L-80 8rnd EUE 2.441” Surf 11,654' JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 71.84’ 71.84’ 13.625” 3.958” Cameron 13-5/8” NOM, PN 2161723-01-01, SN 11317538 - Tubing Hanger 1 11,654' 9,600' N/A 4.000” Discharge, Bolt-On 11,657' 9,600' N/A 4.000” Pump - 400 Series, SF900 (x2), SF1750, SFGH2500 11,748' 9,624' N/A 4.000” Seals - 400 Series, BPBSL 11,764' 9,628' N/A 4.560” Motor - 456 series, FMS2, 180HP 11,788' 9,634' N/A 4.560” Anode, Triplate **Note – Straight Hole Pump Tangent Section 11,521’ to 11,804’ PBTD = 13,558’ TD = 13,636’ MAX HOLE ANGLE = 83.66O Liner Hanger 8,300’ WF-2 RKB-to TBG Head: 71.84’ 7” 26” 1 WF-1 16” 13-3/8” 9-5/8”8-1/2” TOW 8,549’ CTC Packer 2,003’ PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status WF-1 11,842’ 12,148’ 9,647’ 9,699’ 306’ 6 05/22/17 Open WF-1 12,169’ 12,323’ 9,702’ 9,723’ 154’ 6 05/22/17 Open WF-2 12,424’ 12,481’ 9,737’ 9,744’ 57’ 6 05/22/17 Open WF-2 12,518’ 12,551’ 9,748’ 9,752’ 33’ 6 05/22/17 Open WF-2 12,563’ 12,590’ 9,754’ 9,757’ 27’ 6 05/22/17 Open WF-2 12,645’ 12,658’ 9,764’ 9,766’ 13’ 6 05/22/17 Open WF-2 12,704’ 12,860’ 9,771’ 9,791’ 156’ 6 05/22/17 Open WF-2 12,891’ 13,017’ 9,795’ 9,811’ 126’ 6 05/22/17 Open WF-2 13,160’ 13,290’ 9,830’ 9,846’ 130’ 6 05/22/17 Open Well Name:MRF M-28RD API #:50733204140000 Field:McArthur River Start Date:2/16/2024 Permit #:190019 Sundry #:324-083 End Date:3/14/2024 2/16/2024 2/19/2024 2/20/2024 3/5/2024 3/6/2024 3/7/2024 Well Operations Summary Rih w/ tbg punch pinned w/ aluminum and 5' steam t/ 11,751' spang dn several times. pooh all shots fired. Rih w/ PT gauges tools stoped @ 10,520' SLM KB (does not appear to be setting on something solid , p/up and run back several times stopping at different depths. the deepest the tools would go was 10,562' discuss options w/ town and recive new stop depths Continue survey Btm depth 11,545' for 45 min 11,425' for 15 min and 11,325' for 15 min Pooh chk data Good. r/dn and move t/ M-21 R/U to circulate well, prep for pumping. Circ. well with 8.4ppg FIW @3bpm ICP=25psi, FCP=707psi. Still getting gassy oil returns after 1,185bbls pumped. Shut in and blow dwn top driv, let oil cap swap for 2hrs. Start pumping same rate 3bpm, 80psi and catch returns w/53bbls away (mostly water), Static loss rate of 26.5bph. Shut dwn, blow dwn. L/D dbl, 2 pups and pump in sub. Set BPV. Performed state witnessed NFT. Ruled a PASS verbally by inspector. Should recieve official state leter later. R/U Slickline. PT 2500psi, good. Rih w. 2.7 GR seeing paraffin f/ 20' to 500' then clear to hard tag at 11679' SLM from tubing hanger. Pooh and p/up 2-7/8" GS and 2-7/8" AD-2 stop rih t/ 11679' SLM attempt to seer same no joy. pooh did not shear and no marks on pin Test GS on surface GS is sheering properly. Switch to 1.75" tool string w/ 15' steam. Rih w/ 2.75" GS and AD-2 stop t/ 11,679' SLM shear AD stop Can not sheer GS. Pooh w/ light sheer marks on pin. Secure lubricator and shut dn for the night N/D tree and stage in upper well bay. test run hanger lifting XO and install blanking test plug. N/U 13-5/8" 5M riser and BOP'scossisting of-single gate, mud X, choke/kill manual and HRC valve, target 90 t/choke/kill hoses, dbl gate, 2ft spacer and annular. Torque all connections with easy torque. Daily Operations: Continue torque connections on BOPs. Perform abandon platform drill- Good drill. Install lower rams and dress others for install. Wire in pipe skate. Production trouble shoot/fix emergency shut down alarm. Test- Good. Sperry MWD did platform survey for rig up. Welder cont. rebuilding pit equalizers, 3/6 complete. Cont. torque bolts on riser to DSA, break bolts on choke line target 90 and re-position hose so blind ram doors could open and re-torque same. Finish installing rams in dbl gate. Install new dry locks on annular. Make up all koomey lines end to end. Power up Koomey and flush thru all lines. Shut down and fill hydraulic reservoir and charge up bottle bank. Simop-Hook up all Koomey lines, start installing pollution pan under rotary table. Page 1 of 3 Well Name:MRF M-28RD API #:50733204140000 Field:McArthur River Start Date:2/16/2024 Permit #:190019 Sundry #:324-083 End Date:3/14/2024 3/8/2024 3/9/2024 3/10/2024 3/11/2024 3/12/2024 Well Operations Summary Daily Operations: POOH & L/D Esp Pump. M/U New pump & RIH to 2500' on 2 7/8 Tubing. Clean and install pollution pan boot plate under rotary table. @0800hrs drilling package switched to emergency generator power to test- good. Install bell nipple and center up/secure stack. Tighten lower bell nipple boot flange and air up all boots. Power up koomey unit and fix leaks. Function test all BOP components-good. Line up MP and fill stack/riser/CM with H2O. Tighten leak on top annular. M/U 2- 7/8”test jt. and land in well, R/U test pump and chart recorder. Function annular 2X and fix leak on annular control line and koomey pump. Test annular 250 low-good, attempt to test to 2500psi on high-riser connection started leaking, fix same. Re-test high -good. Leak found on annular cap, tighten same. Attempt shell test with upper rams 250psi low-good, stage up for high, shut dwn fix leaks 3x, stage up to 5000psi-good, bleed off pressure. Check all connections for correct torque before state rep arrive in the AM for BOP test. L/D hanger filling hole with 20 BPH. R/U Parker tubing equipment. String up ESP cable to spooler. Perform bare pipe shut in drills with crew. POOH L/D SSSV, Packer, & X nipple, strapping and standing all stands back in derrick. Crushed one joint with slips. L/D same. Cont. POOH f/11180' t/5575'. Spooling ESP power cable and cannon clamps. Fire alarm in quarters, all hands gather for muster. Cut ESP power cable and secure, RIH with stand of tubing and stab floor valve and close same. Secure well, shut down power pack for tongs, jet heater, Tioga heaters and summit unit. Gather all personnel and muster for head count. Post drill meeting. C/O full power cable spool and snake cable to new empty spool from rig floor. Cont. POOH standing back 2 7/8 EUE tubing f/5575' t/1500'. Cont. work w/CanRig on PVT, Test run accumulator-c/o 4-way valve for choke/kill HCR. Trouble shoot /repair Koomey electric motor sparking from J-box. Pull apart snail on #1charge pump and remove hose fitting stuck inside. Perform shell test on 13-5/8”5M BOP to 250/5000psi 5min. charted against top VBR’s w/2-7/8” test jt.-tighten several leaks on CM, grease zert and top ram doors-good test. Cont. test #3-failed kill line demco, Test #6 lower VBR’s failed. Gas alarms and PVT tested-good. Cont. test #4,5,6,8,9 and test #10 annular to 250/2500psi-good. Perform accumulator draw down test-good. Blow down riser and BOP and open lower rams and inspect 2- 7/8” x 5-1/2”VBR’s- deep cut on ODS top seal and pipe didn’t look as if they had closed completely around it. C/O lower VBR’’s for 2- 7/8” solid body rams. Rebuild kill line demco valve. Re-test lower rams-good. L/D test jt. Test blinds and kill line demco-demco failed, leaking choke HRC around the bonnet, BOP test witnessed by Adam Earl. C/O choke HCR valve, fill stack, m/u test jt. and re-test choke HCR, kill line demco valve and blinds-good. L/D test jt., Start to m/u blanking plug retrieval tool and draw works fail to start. Both rig/production electricians trouble shooting system. Simop-bring tubing equipment to rig floor. L/D test jt, p/u 5” elevator on top drive. @20:00hrs brought out Enterprise Lead electrician/maintenance foremen to assist electricians, @ midnight draw works was fixed- 120V signal power for pressure switch on draw works was lost, electrician temporarily borrowed 120V power from rotary table circuit to satisfy signal. They continue to trouble shoot issue in the morning. M/U blanking plug retrieval tool and retrieve same, p/u “T-bar and retrieve BPV, M/U XO, 5ft, 15ft pups and 2 jts 5”dp and engage hanger, filling hole thru top drive and kill line. Pull hanger and packer free w/145k hoist wt.. Monitor well, pulling hanger to the floor @ report time. Page 2 of 3 Well Name:MRF M-28RD API #:50733204140000 Field:McArthur River Start Date:2/16/2024 Permit #:190019 Sundry #:324-083 End Date:3/14/2024 3/13/2024 3/14/2024 Well Operations Summary RIH out of derrick 2-7/8" completion tubing T/11,705' MD. M/U hanger and orientate as per Vault Rep. Terminate ESP cable in hanger as per Summit Rep. Daily Operations: Finished terminating tubing spool with ESP. Land Hanger in wellhead. Perform ESP test- good. N/D BOP's, N/U Production tree. Move pipe skate. Clean pits, Clean wellbay. remove service hoses. Transfer fluid from pits to Trading Bay. Clean pits; Prep to flush service liens and equipment. Stage mud product to sack room. Remove equipment and clean pipe rack. Page 3 of 3 2024-0216_No-Flow_TBU_M-28RD_ae Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2-18-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU M-28RD Hilcorp Alaska LLC PTD 2170260 2-16-2024: I traveled to Trading Bay Unit “Steelhead” Platform to witness a No-Flow test on TBU M-28RD. Ryan Wilcox was the Hilcorp operator on the job. I visually inspected the rig-up and verified calibrations on the pressure gauge and gas flow meter. The tubing and IA (tubing-casing annulus) were connected at surface with isolation valves to read separately and to flow together through the low-flow meter. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 8:45 0 / 0.07 / 273 Shut in for pressure build up 9:00 0.07 /0.09 / 273 9:15 0.12 / 0 / 273 9:30 0.6 / 0.04 / 273 9:45 0.11 / 0.06 / 273 0 0 Open to flow; no rate 9:50 0.01 / 0.05 / 273 Shut info pressure build up 10:05 0.04 / 0.08 / 273 10:20 0.10 / 0.10 / 273 10:35 0.15 / 0.13 / 273 10:50 0.04 / 0 / 273 0 0 Open to flow; no rate 10:55 0.07 / 0 / 273 Shut in for pressure build up 11:10 0.02 / 0.02 / 273 11:25 0.02 / 0 / 273 11:40 0 / 0 / 273 11:55 0.01 / 0 / 273 0 0 Open to flow; no rate 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr There was a gentle whisper of gas each time the well was opened to flow. The test appeared to easily pass our requirements. Attachments: Photos (3) 2024-0216_No-Flow_TBU_M-28RD_ae Page 2 of 3 No-Flow Test – TBU M-28RD (PTD 2170260) Photos by AOGCC Inspector A. Earl 2/16/2024 2024-0216_No-Flow_TBU_M-28RD_ae Page 3 of 3 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,636 N/A Casing Collapse Conductor Surface 1,020psi Intermediate 1,540psi Production 3,220psi Production 4,760psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A McArthur River Hemlock Oil, West Foreland Oil Same 9,889 13,558 9,878 1,237psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017594 / ADL0018730 217-026 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20414-01-00 Hilcorp Alaska, LLC Trading Bay Unit M-28RD Length Size Proposed Pools: 990' 990' L-80 TVD Burst 11,676 6,870psi MD 5,860psi 2,630psi 3,090psi 1,444' 4,027' 497' 1,447' 4,590' 990' 26' 16' 13-3/8" 1,447' 10-3/4"497' 4,590' 497' 11,842 - 13,290 8,052' 7" 9,647 - 9,846 7,051'9-5/8" Other: Replace ESP 2/28/2024 13,636'5,226' 2-7/8" 9,889' Dual Packer D&L Oil Tools w/ WFT vent valve & Baker TE-5 SSSV 544 (MD) 544 (TVD) & 393 (MD) 393 (TVD) 8,549' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Kayla Junke at 3:47 pm, Feb 14, 2024 324-083 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.02.13 14:29:35 - 09'00' Dan Marlowe (1267) A fill cleanout or casing scraper run will trigger the need for another NFT post-RWO. DSR-2/14/23 Initial BOP test to 5000 psi, rated working pressure. Initial annular test to 2500 psi. Subsequent BOP tests to 2500 psi. BJM 2/29/24 10-404 SFD 2/14/2024*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.29 11:51:52 -09'00'02/29/24 RBDMS JSB 030124 ESP Swap RWO Well: M-28RD Well Name:M-28RD API Number:50-733-20414-01-00 Current Status:ESP Oil Producer Leg:Leg B-1 (NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:217-026 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,200 psi @ 9,636’ TVD Intake ESP gauge after 18 days shut in projected forward Max. Potential Surface Pressure: 1237 psi Using 0.1 psi/ft Brief Well Summary M-28RD is a West Foreland only oil producer that was sidetracked to its current bore in 2017. The ESP currently downhole was the original one installed after drilling and has lasted ~6 years. The last casing test was associated with that sidetrack in 2017. No cleanout nor perfs are planned as part of this RWO The goal of this project is to pull and replace the ESP Pertinent wellbore information: - April-2017 sidetrack / completion o 5/18/17: MIT of 7” liner and 9-5/8” casing PASSED to 2500psi (before any perfs shot) o ESP landed with 65k weight in wellhead - Analogue West Foreland ESP swaps o Filtered Inlet Water is an acceptable KWF. Doesn’t damage perfs o Losses with only WF open are minimal Pre-RWO (non-sundried) 1. Conduct No Flow Test per attached procedure a. Notify AOGCC to witness test (48hr notice to AOGCC) b. Bleed well (TBG and IA) to 0 psi c. Rig up test equipment (low pressure gauge, flowmeter, etc.) d. Let well bleed through flow meter until inspector arrives but do not exceed 48 hrs. of total bleed time e. Begin No Flow Test per AOGCC regs / guidance document f. Well has not been pumped on since ESP failure g. No planned RWO activities should invalidate NFT ESP Swap RWO Well: M-28RD RWO Procedure: 1. Ready platform rig Steelhead #51 for RWO operations 2. Circulate well to production: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 68bbls d. IA volume ~710bbls 3. Set BPV/TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Hilcorp’s 13-5/8” RWO BOP stack will be used. This stack has been in service recently with both rig #401 and rig #404 RWO’s 4. BOLDS and unseat hanger and pull up to release packer 5. POOH with 2-7/8” tubing string, packer, and ESP completion 6. PU, RIH with new ESP completion a. No packer nor SSSV is planned b. Results of pre-rig NFT will confirm this 7. Land ESP completion 8. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC 9. Turn well over to production 10. If NFT wasn’t completed pre-rig, will need NFT completed within 14 days Contingency if evidence of excessive fill 1. PU 3-1/2” workstring 2. MU 7” liner cleanout assembly 3. RIH and mill/cleanout 7” liner to target depth = 13,558’ MD (PBTD) 4. POOH and lay down cleanout BHA and workstring Note: If cleanout is performed, a new NFT will be required Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current and Proposed Wellhead Diagram (no changes) 4. BOP Drawing 5. Fluid/Flow Diagrams 6. RWO Sundry Change Form PU, RIH with new ESP completion a.No packer nor SSSV is planned b. Results of pre-rig NFT will confirm this Assuming pre-RWO NFT passes. -bjm A fill cleanout or casing scraper run will trigger the need for another NFT post-RWO. -bjm Hilcorp’s 13-5/8” RWO BOP stack will be used. This stack has been in service recently with both rig #401 and rig #404 RWO’s Updated by: JLL 06/12/17 SCHEMATIC McArthur River Field Steelhead Platform Well: M-28RD PTD: 217-026 API: 50-733-20414-01 Last Completed: 05/26/2017 CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 26” 267/397 Dril-Quip Surf 990’ 16” 75 K-55 Buttress 15.124” Surf 1,447’ 13-3/8”61 K-55 Buttress 12.515” Surf 2,563’ 68 K-55 Buttress 12.415” 2,563’ 4,590’ 10-3/4”51 N-80 Buttress 9.850” Surf 368’ 55.5 N-80 Buttress 9.760” 368’ 497’ 9-5/8”47 N-80 Buttress 8.681” 497’ 5,289’ 47 S-95 Buttress 8.681” 5,289’ 8,549’ (TOW) 7” 29 L-80 DWC/C 6.184” 8,300’ 13,636’ Tubing Detail 2-7/8” 6.4 L-80 8rnd EUE 2.441” Surf 11,676’ JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 71.84’ 71.84’ 13.625” 3.958” Cameron 4-1/2”, 13-5/8” NOM, PN 2161723-01-01, SN 11317538 - Tubing Hanger 1 393’ 393’ 2.312” 4.625” Baker Model TE-5 SSSV 2 544’ 544’ 2.925” 8.500” ESP Dual Packer D&L Oil Tools w/ WFT vent valve 3 618’ 618’ 2.313” 3.23” X-nipple 4 11,676’ 9,605’ N/A 4.000” Discharge, Bolt-On 11,676’ 9,605’ N/A 4.000” Pump – 333 stage Summit SF2700AR 11,747’ 9,623’ N/A 4.000” Seals – Tandem Summit 400 series BPBSL 11,763’ 9,627’ N/A 4.560” Motors – Summit 240HP/2975V/58A 11,798’ 9,636’ N/A 4.560” Centralizer Anode **Note – Straight Hole Pump Tangent Section 11,521’ to 11,804’ PBTD = 13,558’ TD = 13,636’ MAX HOLE ANGLE = 83.66 O 1 Liner Hanger 8,300’ WF-2 RKB-to TBG Head: 71.84’ 7” 26”2 4 3 WF-1 16” 13-3/8” 9-5/8”8-1/2” TOW 8,549’ X CTC Packer 2,003’ PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status WF-1 11,842’ 12,148’ 9,647’ 9,699’ 306’ 6 05/22/17 Open WF-1 12,169’ 12,323’ 9,702’ 9,723’ 154’ 6 05/22/17 Open WF-2 12,424’ 12,481’ 9,737’ 9,744’ 57’ 6 05/22/17 Open WF-2 12,518’ 12,551’ 9,748’ 9,752’ 33’ 6 05/22/17 Open WF-2 12,563’ 12,590’ 9,754’ 9,757’ 27’ 6 05/22/17 Open WF-2 12,645’ 12,658’ 9,764’ 9,766’ 13’ 6 05/22/17 Open WF-2 12,704’ 12,860’ 9,771’ 9,791’ 156’ 6 05/22/17 Open WF-2 12,891’ 13,017’ 9,795’ 9,811’ 126’ 6 05/22/17 Open WF-2 13,160’ 13,290’ 9,830’ 9,846’ 130’ 6 05/22/17 Open Updated by: JLL 02/13/24 PROPOSED McArthur River Field Steelhead Platform Well: M-28RD PTD: 217-026 API: 50-733-20414-01 Last Completed: FUTURE CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM 26” 267/397 Dril-Quip Surf 990’ 16” 75 K-55 Buttress 15.124” Surf 1,447’ 13-3/8”61 K-55 Buttress 12.515” Surf 2,563’ 68 K-55 Buttress 12.415” 2,563’ 4,590’ 10-3/4”51 N-80 Buttress 9.850” Surf 368’ 55.5 N-80 Buttress 9.760” 368’ 497’ 9-5/8”47 N-80 Buttress 8.681” 497’ 5,289’ 47 S-95 Buttress 8.681” 5,289’ 8,549’ (TOW) 7” 29 L-80 DWC/C 6.184” 8,300’ 13,636’ Tubing Detail 2-7/8” 6.4 L-80 8rnd EUE 2.441” Surf ±11,675’ JEWELRY DETAIL No Depth MD Depth TVD ID OD Item 71.84’ 71.84’ 13.625” 3.958” Cameron 4-1/2”, 13-5/8” NOM, PN 2161723-01-01, SN 11317538 - Tubing Hanger 1 ±11,675’ ±9,605’ N/A 4.000” Discharge, Bolt-On N/A 4.000” Pump N/A 4.000” Seals N/A 4.560” Motors N/A 4.560” Centralizer Anode **Note – Straight Hole Pump Tangent Section 11,521’ to 11,804’ PBTD = 13,558’ TD = 13,636’ MAX HOLE ANGLE = 83.66O Liner Hanger 8,300’ WF-2 RKB-to TBG Head: 71.84’ 7” 26” 1 WF-1 16” 13-3/8” 9-5/8”8-1/2” TOW 8,549’ CTC Packer 2,003’ PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Feet SPF Date Status WF-1 11,842’ 12,148’ 9,647’ 9,699’ 306’ 6 05/22/17 Open WF-1 12,169’ 12,323’ 9,702’ 9,723’ 154’ 6 05/22/17 Open WF-2 12,424’ 12,481’ 9,737’ 9,744’ 57’ 6 05/22/17 Open WF-2 12,518’ 12,551’ 9,748’ 9,752’ 33’ 6 05/22/17 Open WF-2 12,563’ 12,590’ 9,754’ 9,757’ 27’ 6 05/22/17 Open WF-2 12,645’ 12,658’ 9,764’ 9,766’ 13’ 6 05/22/17 Open WF-2 12,704’ 12,860’ 9,771’ 9,791’ 156’ 6 05/22/17 Open WF-2 12,891’ 13,017’ 9,795’ 9,811’ 126’ 6 05/22/17 Open WF-2 13,160’ 13,290’ 9,830’ 9,846’ 130’ 6 05/22/17 Open Steelhead Platform M-28 Current 02/13/2024 Tubing head, McEvoy SL-P, 13 5/8 5M FE top X 16 ¾ 5M FE bottom, w/ 2- 2 1/16 5M SSO Steelhead Platform M-28 26 X 16 X 13 3/8 X 10 ¾ and 9 5/8 X 4 1/2 Tubing hanger, McEvoy SL- EP-ESP, 13 5/8 X 4 ½ IBT lift and susp, w/ 4'’ Type H BPV profile, 4- 3/8 continuous control lines Starting head, FMC, 30'’ MSS FE X 26'’ butt weld Adapter spool, FMC-A-5-S 30'’ MSS stdd bottom X 21 ¼ 2M FMC speedlock top, w/ 2- 2'’ LPO Unihead, FMC Type 2, 16 ¾ 5M FE top X 21 ¼ 2M FMC speedlock bottom, w/ 4- 2 1/16 5M SSO Tubing head, FMC-TC-60, spec for unihead, 16 ¾ 5M FE top X 16 ¾ 5M stdd bottom, w/ 2- 2 1/16 5M SSO Valve, FMC-120, 2 1/16 5M FE, HWO, AA 26'’ 16'’ 13 3/8'’ 10 ¾’’ 3 ½ and 2 7/8 Valve, Swab, FMC-120, 4 1/16 5M FE, HWO, DD Valve, Master,FMC-120, 4 1/16 5M FE, HWO, DD Valve, upper master, WKM-M, SSV, 4 1/16 5M FE, w/ 18'’ Omni operator, EE Valve, wing, FMC-120, 4 1/16 5M FE, HWO, DD BHTA, FMC, B-11-A0, 4 1/16 5M FE Steelhead Platform M-28 and M-21 workover 02/03/2024 13 5/8 5M Shaffer Shaffer SL 1.83' 2.83' 3.74' 18.83' 21.75' Mud Cross 13 5/8 5M FE X FE w/ 3 1/8 5M EFO Riser 13 5/8 5M #13 API hub X 13 5/8 5M FE Riser 13 5/8 5M #13 API hub X 13 5/8 5M FE 2.00'Spacer spool installed for use of lift cradle on studded BOP 2 7/8-5.5 variables Blinds Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well M-28RD (PTD 217-026) Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Asset Team Operations Manager Date Prepared: First Call Operations Engineer Date 1 Junke, Kayla M (OGC) From:McLellan, Bryan J (OGC) Sent:Thursday, February 29, 2024 4:34 PM To:Ryan Rupert; Regg, James B (OGC) Cc:Shane Hauck; Clint Chanley; Sloan Sunderland; Dan Marlowe; Juanita Lovett Subject:RE: M-28RD RWO (PTD#217-026) BOP change Ryan, The change in BOP stack is approved for use on the scope of work covered under sundry 324-083. BOP tesƟng requirements listed in the sundry sƟll apply. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Thursday, February 29, 2024 4:28 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Shane Hauck <shauck@hilcorp.com>; Clint Chanley <cchanley@hilcorp.com>; Sloan Sunderland <ssunderland@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: M-28RD RWO (PTD#217-026) BOP change Jim- Looks like we’ll be in a posiƟon to start our M-28RD ESP swap RWO as soon as Sunday 3/3. We plan on uƟlizing the Steelhead #51 drilling rig for this RWO as described in the sundry. We plan to uƟlize rig #51 for drilling later this spring. The BOP’s we plan on using to drill with rig #51 just got back in state. We’d like to use this BOP (diagram below) for the M-28RD RWO to warm it up for drilling operaƟons. Hilcorp requests a change to approved sundry #324-083 to use the aƩached BOPE. Please advise if this is acceptable. Per the sundry, these will be tested to full rated working pressure = 5000psi, and the annular to 2500psi. Subsequent tests will be to 2500psi. Thank you, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. 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O 0 J J_ P V) Z Z a3 /�/ a7 co II 2 c 0 0 W ai 0 d' iL EI �W♦ 0,N V J J co rn a I E O E J° E Q Z v) w - p p 0 w N J n C ar > D E o co 2 0 0 CL ti c II r 0 O N nE I V � U ®_ Co N C w C) a) o ›. O E op C N V . _ to Z .@s COiii N 0 a) E I m Lo o 1- C70 c c COa> 0co 0 c o C cg ...7..- ea p c a) I a m OI II lb 1 Z o 2 - co 0 0 2 0 as Z d r r 3 00 03 z N N ' C) I N M lbw- o to > _ r n m N _o d = N CL N se 0 M d m 1 0 0 o c •- > p co c 1-O. cc 2 1 Z c N o 14i i I o _ Q O 0 C c U +' a) U r J N N .c. I a) co (. 04 O a o tlol E Q 0 • D E p D E d E E a 2 o a 0 0 0 0 0 • 217026 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 2 8 3 C ED Tele: 907 777 8337 iI 1 5 RECEIVDATA LOGGED Ifikirrla 11:i .;i.LTA, Fax: 907 777-8510 c r23/2017 JUN 26 2011 E-mail: doudean@hilcorp.com M. K.BENDER DATE: 6/26/2017 AOGCC To: AOGCC Makana Bender 333 W. 7t" Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL BU M-28RD CAN RIG FINAL MUDLOG DATA CD Daily Reports 6/26/2017 9:43 AM File folder DML Data 6/26/2017 9:44 AM File folder Final Well Report 6/26/2017 9:35 AM File folder LAS Data 6/26/2017 9:35 AM File folder Log PDFs 6/26/2017 9:37 AM File folder Log TIFFs 6/26/2017 9:39 AM File folder Sample Photography 6/26/2017 9:43 AM File folder Show Reports 6/26/2017 9:43 AM File folder HALLIBURTON FINAL WELL DATA CD _Log Viewers 6/26/2017 9:23 AM File folder CGM 6/26/2017 9:23 AM File folder Definitive Survey 6/26/2017 9:23 AM File folder EMF 6/26/2017 9:21 AM File folder LAS 6/26/2017 9:22 AM File folder PDF 6/26/2017 9:22 AM File folder TIFF 6/26/2017 9:22 AM File folder Prints: ROP DGR EWR-Phase4 ALD CTN MD DGR EWR-Phase 4 ALD CTN TVD SLUMBERGER CBL DATA CD 1 DLIS Data 6/26/2017 9:26 AM File folder {.. LAS Data 6/26/2017 9:27 AM File folder ! Log 6/26/2017 9:27 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By� ✓� 15_.en4 Date: 4 RECEIVED • STATE OF ALASKA • JUN 2 2 2.017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANC 1 a.Well Status: Oil Q Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development O.. Exploratory ❑ GINJ ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 5/26/2017 217-026/317-129 3.Address: 7. Date Spudded: 15.API Number: 3800 Centerpoint Drive, Suite 1400,Anchorage,AK 99503 May 1,201750-733-20414-01-00 , 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1000'FNL,557'FWL,Sec 33,T9N, R13W,SM,AK May 10,2017TBU M-28RD Top of Productive Interval: 9. Ref Elevations: KB: 160' 17. Field/Pool(s):McArthur River Field 794'FNL,2380'FWL,Sec 28,T9N, R13W,SM,AK GL: N/A BF:72' West Foreland Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 938'FSL,2368'FEL,Sec 21,T9N, R13W,SM,AK 13,558'MD/9,884'TVD ADL018730/ADL017594 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 214174 y- 2499500 Zone- 4 13,636'MD/9,888'TVD N/A TPI: x- 216122 y- 2504941 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 216692 y- 2506659 Zone- 4393'MD/393'TVD N/A 5. Directional or Inclination Survey: Yes t J (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 187' (ft MSL) 8,549'MD/7,051'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, EWR-Phase 4,CTN,ALD,ABG(MD&TVD);CEMENT BOND LOG DSLT-GR-CCL 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 7" 29# L-80 8,300' 13,636' 6,861' 9,888' 8-1/2" 544 sx r•3`f d/sc 24.Open to production or injection? Yes ❑✓ No ❑ 25.TUBING RECORD If Yes, list each interval open(MDITVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 2-7/8" 11,798' 544'MD/544'TVD See attached schematic ri, f -''t''' 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. I TA LO'11– Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283(i)(2)attach electronic and printed information L,- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 5/27/2017 ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 6/5/2017 24 Test Period —968.7 240.2 220.4 N/A 248 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 73 72 24-Hour Rate — 968.7 240.2 220.4 31 Form 10-407 Revised 5/2017 ,,1 74//7._ Q CONTINUENPAGE RBDMS l, - JUN 2 6 201PubmitORIGINIAL onl • • 28.CORE DATA Conventional Core(s): Yes ❑ No Q 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 ❑., Permafrost-Top N/A N/A If yes,list intervals and formations tested, briefly summarizing test results. Permafrost-Base N/A N/A Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval W. Foreland 11,842' 9,647' information, including reports,per 20 AAC 25.071. COAL_39 10,237 8,650 G1 10,302 8,714 G2 10,381 8,792 H 1 X 10,642 9,039 Coal 59 10,689 9,082 HK2 10,736 9,125 HK3 10,914 9,271 HK4 11,031 9,355 HK5 11,155 9,430 HK6 11,406 9,535 WF 11,847 9,648 WF2 12,385 9,732 WF3 13,310 9,848 Formation at total depth: West Foreland 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys,Csg and Cmt Report,Days vs Depth 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: Paul Mazzolini Contact Name: Cody Dinger Authorized Title:Drilling Manager Contact Email: cdinger(p�hllcorp.com Authorized, ®6 J Contact Phone: 777-8389 Signature: Date: z�/7O/7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 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 0 • McArthur River Field Steelhead Platform SCHEMATIC Well: M-28RD PTD: 217-026 API:50-733-20414-01 Hilcorp Alaska,LLC Last Completed:05/26/2017 RKB-to TBG Head:71.84' J CASING DETAIL SIZE WT GRADE CONN ID TOP BOTTOM ® 26" 267/397 Druip Surf 990' 2 16" 75 K-55 Buttressil-Q15.124" Surf 1,447' x 26 61 K-55 Buttress 12.515" Surf 2,563' 3 13 3/8" AtIl LL :TC 68 K-55 Buttress 12.415" 2,563' 4,590' 'acker 16" 10-3/4" 51 N-80 Buttress 9.850" Surf 368' ',003' 55.5 N-80 Buttress 9.760" 368' 497' 9-5/8" 47 N-80 Buttress 8.681" 497' 5,289' 47 S-95 Buttress 8.681" 5,289' 8,549'(TOW) 13-3/8" 7" 29 L-80 DWC/C 6.184" 8,300' 13,636' Tubing Detail 2-7/8" 6.4 L-80 8rnd EUE 2.441" Surf 11,676' JEWELRY DETAIL No Depth Depth ID OD Item MD TVD 71.84' 71.84' 13.625" 3.958" Cameron 4-1/2",13-5/8"NOM,PN 2161723-01-01,SN 11317538-Tubing Hanger 1 393' 393' 2.379" 4.62" Baker Model TE-5 SSSV Liner Hanger 2 544' 544' 2.925" 3.68" ESP Dual Packer D&L Oil Tools w/WFT vent valve 8,300' 3 618' 618' 2.313" 3.23" X-nipple E 11,676' 9,605' N/A 4.00" Discharge,Bolt-On 11,676' 9,605' N/A 4.00" Pump-333 stage Summit SF2700AR Q 4 11,747' 9,623' N/A 4.00" Seals-Tandem Summit 400 series BPBSL 8-1/2"TOW 9-5/8" 11,763' 9,627' N/A 4.560" Motors-Summit 240HP/2975V/58A 8,549' 11,798' 9,636' N/A 4.560" Centralizer Anode rw -bc- S q�L` **Note-Straight Hole Pump Tangent Section 11,521'to 11,804' .- it III 11"`--34)-1 y '-' PERFORATION DATA 4 Top Btm Top Btm Zone Feet SPF Date Status (MD) (MD) (TVD) (TVD) WF-1 11,842' 12,148' 9,647' 9,699' 306' 6 05/22/17 Open WF-1 12,169' 12,323' 9,702' 9,723' 154' 6 05/22/17 Open WF-2 12,424' 12,481' 9,737' 9,744' 57' 6 05/22/17 Open WF-2 12,518' 12,551' 9,748' 9,752' 33' 6 05/22/17 Open WF-1 WE-2 12,563' 12,590' 9,754' 9,757' 27' 6 05/22/17 Open WF-2 12,645' 12,658' 9,764' 9,766' 13' 6 05/22/17 Open WF-2 12,704' 12,860' 9,771' 9,791' 156' 6 05/22/17 Open WF-2 12,891' 13,017' 9,795' 9,811' 126' 6 05/22/17 Open WF-2 WF-2 13,160' 13,290' 9,830' 9,846' 130' 6 05/22/17 Open CBL in LW <. L ' 7" 4`), b.:hi f'a q gi.t"- PBTD=13,558' TD=13,636' MAX HOLE ANGLE=83.66° Updated by:JLL 06/12/17 • Hilcorp Energy Company Composite Report Well Name: MRF M-28RD Field: County/State: CIO,Alaska (LAT/LONG): svation(RKB): API#: 50-733-20414-01-00 Spud Date: Job Name: 1710804P M-28RD PreDrill Contractor AFE#: AFE$: 4/19/2017 Prep for rig move,finish install of new cement hoses,replace accumulator 4-way valves,&remove ODS bottom stairs for rig move.SIMOPS tested M-29 tree to 250/3000 psi for 15 min&void to 250/5000 psi for 15 min.,Remove rotary table cover,free up rotary table,free up rotary lock&repair lever lock,&service/ grease table. Remove Kelly hose from TD&standpipe.Move hose to deck for storage.SIMOP continue work on 4-way accumulator valves.,Skid rig from M- 29A to M-28RD. Remove lower earthquake clamps,purge new hydraulic lines for skid cylinders&skid lower sub base.,Remove upper sub base earthquake clamps,lower HP mud hose from sub base&skid rig over M-28RD.,Install earthquake clamps on upper&lower sub base.Install HP mud line to sub base HP mud line.,Complete service/grease of rotary table&install cover.Take on FIW to pits&line up both mud pumps.Mobilize kelly hose to rig floor.Install lower stairs on ODS of sub base.,Rig up to circulate tubing&9-5/8"X3-1/2"annulus.SIMOPS install kelly hose.,Pressure test circulating lines to 250/3000 psi, good.SIMOPS installing safety clamps&cables on kelly hose.Rig accepted at 06:00 4/20/2017.,M-28 initial pressures @ 22:00 hrs on 04-19-17;9-5/8"X3- 1/2"=78 psi,13-3/8"X9-5/8"=310 psi,16"X13-3/8"=260 psi,26"X16"=260 psi,31"X26"=144 psi. 4/20/2017 Finish pressure testing circulating lines.Line up to pump down tubing,taking returns from 9-5/8"X3-1/2"IA.,PJSM with rig crew&production.Pump FIW down tubing&taking returns from the IA,initial rate 2 bpm,50 psi,no returns.Pressure increase at 65 bbls away,to 630 psi at 3 bpm. Pressure stabilized at 2475 psi,3 bpm,150 bbls away no returns. Pumped 1200 bbls,FCP 2470 psi at 3 bpm with no returns.,Rig down circulating hoses from tree&blow down.,Remove Otis connection flange from tree.Install flange X 4-1/2 IF,2 jts 5"DP, FOSV,&XO to wireline entry sub.PT 300/3000 psi,good. Blow down Iines.,Rig up Pollard E-line,arm guns,and rig up pump-in sub to mud manifold.,TIH with guns on E-line,pert tubing f/10,005-10008'MD.SIMOP offload 5" DP to top deck.,TOH with E-line,stand back wire line head,&rig down.,Line up&circulate down tubing,with returns from IA to production.Circulate at 6 bpm =144 psi,7 bpm=366 psi,8 bpm=2049 psi.Pumped 1494 bbls to see returns to surface.While pumping surface to surface,observe 3.5 bpm returns while pumping at 8 bpm.FCP 8 bpm,2000 psi,total pumped 3400 bbls.SIMOP build 80 bbls salt pill.,Pump and spot 80 bbl,sized salt pill outside the tubing.Shut down to observe pressure on tubing&IA at 0 psi.Open to atmosphere to observe well on a vacuum,both tubing&IA.,Remove flange X 4-1/2 IF,2 jts 5"DP, FOSV,&head pin from top of tree.Install BPV.,Nipple down tree.,M-28 wellhead pressures @ 24:00 hrs;9-518"X3-1/2"=84 psi,13-3/8"X9-5/8"=310 psi, 16"X13-3/8"=260 psi,26"X16"=260 psi,31"X26"=144 psi. 4/21/2017 Finish nipple down of tree&rack back in the upper well bay..NIDoIe uo BOP's.install high pressure risers,set BOP's,bolt up kill&choke hoses.SIMOP clean mud pumps&assist with off load of mud product to dry storage room.,Nipple up BOP's,install all Koomey lines,both air boot flanges,&flow riser.SIMOP grease choke manifold&mud cross valves.,Mobilize&make up 5"test tools.Energize Koomey system& Function Check Blind Rams,Annular, HCR kill& choke valves.,Line up to test kelly hose and find test manifold plugged off.Trace down plug&clear.,Attempt to test kelly hose to 5000 psi.Hammer union at top of stand pipe leaking.Tighten&attempt to retest several times.,Beain testina R(7P's observe gray locks leaking on 2nd test.Tighten&retest to find choke HCR leaking from rear seal.,Blow down choke line&stack. Repair choke HCR rear seal.SIMOP Begin work on kelly hose leak.,M-28 wellhead pressures;9- 5/8"X3-1/2"=65 psi, 13-3/8"X9-518"=280 psi, 16"X13-318"=260 psi,26"X16"=260 psi,31"X26"=150 psi. 4/22/2017 Pressure Testing Blow Out Equipment On 5"D.P.Test 1 Through 2 Pressure Testina to 250psi Low&3.500osi High($undry#317-088)-Had a Fail/Pass at The Hubbeed Connection That Lands Out In The Upper Well Bay-Also a Fail/Pass on Choke Line HCR -Kelly Hose Leaking at Connection To Stand Pipe- Blow Down Stack to Work On Choke Side HCR-Remove Kelly Hose At Stand Pipe Extension-Repack Choke Side HCR Stem.,Cont Pressure Testing 13 5/8 5M BOP Equipment-on 5"-Note Witness Of BOP Test Waived By AOGCC Mr.Mike Quick.,Prep to Change Out Test Joints-Koomey Drawdown Test While Rigging for 3 1/2"Test.,Lay Out 5"Test Joint and Equipment-Pick Up 3 1/2"IBT Test Joint and Equipment-Clean Up Hammer Unions on Stand Pipe Extension.,Cont Pressure Testing 13 5/8 5M BOPE-Re Hang Kelly Hose.,Cont Pressure Testing on 3 1/2"-Completed Pressure Test Of BOP Equipment.,Lay Down 3 1/2"Test Joint And Equipment-Had to Turn Kelly Hose to Get The Correct Loop For Running in Derrick-Pressure Test Kelly Hose to 5,000psi.,Pick Up 5"Landing Joint with 4 1/2"IBT Crossover For Hanger Lift Threads-Engage Hanger Lift Threads-Make Up Top Drive-Start Circulation to Production Test Separator-Worked Rate Up To 7Bbl/Min-Caught Pressure(300ps)i With 55BbI Pumped(Cal 6,300'of Tubing)-Increased Rate to 8Bbl/Min with 1,500psi- Fluid Returns to Test with an additional 220Bbl of Fluid Pumped(Cal 3,588 of Annular Fill).,Rig up Summit Equipment For Pulling ESP While Circulating Well- Going Downhole at 8bbl/Min Rate With 3 to 3.5BbI/Min Returns to Test- Pump 92bbI Sized Salt Pill and Displaced Same Out Side D.P.Flow check,well on a vac.,PJSM discussing hazards,mitigation's,& bare pipe shut in.BOLDS&pull hanger free w/155K.Pull hanger to rig floor,PU 175K.Filling the back side static loss rate at 36 bph.Stand back landing joint,lay down XO's&hanger.,TOH w/3-1/2"tubing&ESP f/10107'-9974'MD, PU 170K,feeding ESP/control line down to spoolers on the deck.Hang sheaves in the derrick&secure ESP/control line to spoolers.,TOH w/3-1/2"tubing&ESP f/9974'-7729'MD,PU 152K.Loss rate increasing to 126 bph.,M-28 wellhead pressures;13-3/8"X9-5/8"=300 psi,16"X13-3/8"=260 psi,26"X16"=280 psi,31"X26"=150 psi. 4/23/2017 Cont Laving Down 3 1/2"9.2#Super Max ESP Completion F/7729 to 5160-Losses Ranging From 115 to 154 Bbl/Hr Loss Rate-Keeping Hole Full-PU at 5,160'=120K,S.O.100K.,Change Out Spool For ESP Elect Wire-1hr Loss Rate 128BbI.,Rig Service.,Cont Laying Down 3 1/2"9.2#Super Max ESP Completion F/5,160' to 175-Losses 118 to 135 bbl/hr.,Clear&clean rig floor to lay down ESP pumps.Mobilize Summit tools to rig floor. Rig down Weatherford tongs.,Lay down ESP pump assembly per Summit.Total clamp count:156-2'cannon clamps, 1 -4'cannon clamp,14-wide pump clamps,& 10-narrow pump clamps.,Clear&clean rig floor of all completion tools,clamps&equipment.,Mobilize wear bushing&setting tool to rig floor.Set 12-1/2"ID wear bushing&run in 2 lock down screws.,Begin picking up BHA 1:8 1/2"Mill Tooth Bit,9 5/8 47#Csng Scraper, Bit Sub With Float,4 1/2 IF Flex Joint, Upper String Mill,1 Jnt 5"HW,Bumper Sub,Jar,&18 Jnts 5"HW.,M-28 wellhead pressures;13-318"X9-5/8"=295 psi, 16"X13-3/8"=260 psi,26"X16"=280 psi,31"X26"=150 psi. Losses for 24 hrs 2926 bbls. • • 4/24/2017 Continue picking up BHA 1:8 1/2"Mill Tooth Bit,9 5/8 47#Csng Scraper,Bit Sub With Float,4 1/2 IF Flex Joint, Upper String Mill, 1 Jnt 5"HW,Bumper Sub,&Jar.,Single in the hole w/18 Jnts 5"HW.,Single in the hole w/5",19.5#,S-135 DP;ft 626'-1730'MD,PU 115K,SO 112K.,Service rig.,Single in the hole WI 5",19.5#,S-135 DP;f/1730'-5760'MD, PU 185K,SO 160K.,Found birds nest&excessive wear on cable to skate backstop.Developed plan to pick up DP from catwalk using rig floor air hoist.PJSM with crew.,Single in the hole w/5",19.5#,S-135 DP;f/5760'-6660'MD, PU 225K,SO 165K.,Single in the hole w/5",19.5#,S-135 DP;f/6660'-9249'MD,PU 274K,SO 192K.,TOH f/9249'-8207'MD,PU 265K.,Mobilize,strap&tally 5"DP to single in the hole.,M-28 wellhead pressures;13-318"X9-5/8"=280 psi,16"X13-3/8"=260 psi,26"X16"=320 psi,31"X26"=150 psi.Losses for 24 hrs 2374 bbls. 4/25/2017 Single in the hole w/5",19.5#,S-135 DP;f/8207'-9249'MD,PU 274K,SO 192K.,TOH f/9249'-5080'MD racking 5"DP in derrick.,Cut&slip 65'of drill line. Inspect brake bands&Iinkage.,Service top drive,blocks,drawworks,&crown.,TOH f/5080'-70'MD,racking back 5"DP&HWDP.,Lay down BHA 1,clear equipment from rig floor.,Mobilize E-Line tools&lubricator to rig floor.Rig up E-Line sheave&make up 9-5/8"cement retainer.,TIH w/9-5/8"cement retainer on E-Line.Set top of retainer at 9098'MD.Perform logs&TON.Circulate across the top of the hole,observe losses stop after retainer set.,Rig down E-Line tools,sheave,&lubricator.,Mobilize cementing BHA to rig floor.Make up BHA 2,407'MD;Shift/stab-in tool,pup w/bowspring,XO 2-7/8"EUE X 3-1/2"EUE, XO 3-1/2"EUE X 3-1/2"SM;12-3-1/2"Tubing;XO 3-1/2"SM X 4-1/2"IF.,TIH ft 407'-2777 MD w/cementing string on 5"DP.,M-28 wellhead pressures; 13- 3/8"X9-518"=320 psi, 16"X13-318"=260 psi,26"X16"=325 psi,31"X26"=150 psi.Losses for 24 hrs 1581 bbls. 4/26/2017 TIH fl 2777'-6623'MD w/cementing string on 5"DP.,Repair hose leaking on Iron Roughneck.,TIH f/6623'-7961'MD w/cementing string on 5"DP.,De- energize SCR&remove air conditioner from top of SCR house with crane.,TIH f/7961'-9029'MD w/cementing string on 5"DP.,Circulate string volume at 9029'MD,PU 252K,SO 185K. Record baseline circulating rates 2-8 bpm,50-420 psi.,TIH f/9029'-9102'MD,tag up on retainer @ 9102'MD,sting into retainer to measure spaceout for cementing.,Service rig,top drive,blocks&drawworks.,Rig up cementing equipment on rig floor,fluid pack lines,PT lines 600/4000 psi.Sting into retainer&attempt to establish baseline injection rate/psi with cement pump,pressure up not consistent with previous baseline.Swap back to rig pump&observe same pressure build up.Unsting from retainer&observe pressure bleed off.Wash down,stinging into retainer to see psi drop off& no returns to confirm success.,Obtain injection rate with cement pump 2-6 bpm,45-450 psi,pumping 18 bbls fresh H2O flush.Batch up&pump 164 bbls of 15.8 ppg,class G,plug blend cement at 2-3 bpm,75-125 psi.Pump 20 bbls of fresh H2O flush at 4-5 bpm,75 psi.Swap to rig&displace cement with 137 bbls of FIW; ICP 7-8 bpm=120-160 psi.,Caught pressure at 93 bbls away&reduce rate to 3.5 bpm=215 psi; 100 bbls away 3 bpm=400 psi;120 bbls away 2 bpm=1650 psi;FCP 1 bpm=2000 psi.Shut down&unsting from retainer.TOH ft 9102'-8610'MD,PU 262K,laying 5 bbl of cement on top of retainer.While pumping cement pump pressure jacked up&down throughout job making pressure difficult to read&interfered with stroke counter accurately reading bbls pumped.,We were able to verify bbls pumped with H2O/cement ratio.Flow meter for H2O matched manual strap during the job.Calculations at completion of job verified correct bbls of cement pumped.HES cementers also had an issue with the water knife valve,controlling water to cement ratio.CIP @ 18:25 hrs.,Circulate surface to surface at 9 bpm,540 psi with nerf ball dropped to wipe cementing string.,PJSM,shut down SCR's,install new air conditioner with crane on SCR house.,TOH f/8610'-4545'MD,PU 152K,SO 135K.,Service rig,top drive,drawworks,&iron roughneck.,TOH ft 4545-407'MD.,Lay down BHA 2,cementing assembly.,Rig up&trouble shoot test equipment for casing test.,Test 9-5/8",47#,N-80 casing to cement retainer©9102'MD.Pumped 6 bbls at 8 spm to 2700psi&shut in.Test charted for 30 minutes. Bled back 6 bbls.,M-28 wellhead pressures;13-3/8"X9-5/8"=320 psi,16"X13-3/8"=260 psi,26"X16"= 325 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls. 4/27/2017 Rig up E-line,make up&TIN w/7.71"cast iron bridge plug,set same at 8573'MD.TOH&rig down E-line.,Remove wear bushing.,Mobilize whipstock&BHA 3 to rig floor.Make up whipstock&orient wI MWD,RFO 194.,Shallow hole test MWD at 420 gpm,650 psi,good signal.,lnstall BHA mill assembly to Gen II whipstock.,TIH w/BHA#3 f/97-8513'MD,PU 275K,SO 190K,fill pipe every 20 stands.,Stage up pumps to 550 gpm, 1500 psi, PU 275K,SO 190.Orient whipstock working turns with reciprocation to 53 degrees left.Tag top of CIBP at 8572'MD with 3K down weight.Observe anchor set w/15K WOB, 175K. Pull 15K over to verify anchor set.Slack off to observe brass bolt shear w/30K WOB,160K.Top of ramp at 8550'MD,bottom of ramp 8567'MD.,TOH f/8550'- 8300'MD,PU 275K,SO 185K.,Remove subs&handling equipment that are not needed from rig floor.Clear all rig floor drains&water test same.Work on rigging up pressure washer w/base oil to shakers&rig floor.Test spare lower kelly valve.Clean out SCR house.Test vac system for rig.Flush return line for# 2 hopper so line can be replaced by welder.,M-28 wellhead pressures;13-3/8"X9-5/8"=360 psi, 16"X13-3/8"=260 psi,26"X16"=330 psi,31"X26"=140 psi. Losses for 24 hrs 0 bbls. 4/28/2017 Re-route steam condensate lines to drain on upper deck.Rig up Geospan unit to mud manifold&bleed off line to pits.Begin removal of#2 hopper discharge line.Repair centrifuge feed pump.Continue cleaning rig floor.Continue research&troubleshoot air conditioner install.,TIH&space out f/8300'-8549'MD,PU 275,SO 180,above whipstock for E-line Gyro logging run.,Trouble shoot leak between trip tanks, continue removal of#2 hopper discharge line,continue work on centrifuge feed pump,rig up&test vac system for rig floor.,Log 9-5/8"casing ft 8475'to surface.Test gas detection system with AOGCC Rep Guy Cook. Continue removal of#2 hopper discharge line,continue work on centrifuge feed pump&punch list for drilling w/OBM.,Rig down E-line&lay down Gyro tools. TOH ft 8549'-8394'MD,PU 275K,SO 180K.,Install new section of#2 hopper discharge line.Transfer base OBM to upright tanks from pits.Clean drums from mixing mud.Test Geospan unit 250/3500 psi,good.,Continue cleaning around rig.Seal up cracks&holes around rig floor.Finish 2nd batch of 247 bbls of OBM. Hook up lines&transfer OBM from pits to uprights on top deck.Finish installation of#2 hopper discharge line.Grease choke valves&service rig.,M-28 wellhead pressures;13-3/8"X9-518"=380 psi,16"X13-3/8"=260 psi,26"X16"=325 psi,31"X26"=140 psi. Losses for 24 hrs 0 bbls. 4/29/2017 Rig up to install landing extention on east side rig floor stairway.Torque up flange on#2 hopper discharge line.Make manifolds for LVT uprights.Install skate camera system.Continue building 230 bbls of OBM.,Continue install of landing extention on east side rig floor stairway.Flood test rig floor&seal up leaks to prevent OBM from leaking to lower levels.Change out cable for skate backstop.Lay out felt around rig.,Rig up to test BOP's;mobilize test tools to rig floor. Pull 2 singles PU 275K/SO 180K,install test plug,hang off string,&make up test equipment.Fluid pack all lines&shell test.,Test BOP's with 5"test joint.All tests to 250/3500 psi for 5 minutes each,recorded on chart.#1 Annular,CMV 1,2,3,12,13,14,dart valve, demco kill line valve,upper IBOP;#2 Upper pipe rams, FOSV,CMV's 4,5,6,kill line HCR,lower IBOP;#3 CMV 7,8,9,Manual Kill;#4 CMV's 10, 11;#5 Super-choke&manual choke bleed down ft 1500 psi; #6 Choke NCR;#7 Manual choke line valve;#8 Lower rams;#9 Blind rams;,Accumulator System: Initial system pressure 3000 psi;Pressure After Closure 1400 psi;Attained 200 psi in 35 seconds;Attained Full Pressure in 197 seconds;8 Nitrogen Bottles Averaged Pressure 2500 psi.Tested pit level alarms&flow indicator.Witness waived by AOGCC Rep.Jim Regg.,Lay down test equipment,blow down all lines,&pull test plug to rig floor.TIN w/2 joints to 8395'MD PU275K,SO 180K.,Continue pre-OBM punch Iist.,M-28 wellhead pressures;13-3/8"X9-5/8"=380 psi,16"X13-3/8"=260 psi,26"X16"=320 psi,31"X26"=145 psi.Losses for 24 hrs 0 bbls. 4/30/2017 Change out expanded metal cover over SCR's,change out isolation valve between trip tanks,plumb in centrifuge feed line,assist crane crew with jore flats for iso-tanks,install 12"dump valve below shakers.weight up OBM f/7.6-8.9 ppg.,Continue work on 12"dump line,modify rig floor mats for better traction/fit, clean SCR house roof,install softeners for cement hose&HP pressure mud line,lay out hoses for displacement,&start hooking up flow box hose.,Continue welding/install 12"dump line,install 10"drain line in lower BOP deck,&continue pre-OBM checklist.,Trouble shoot drawworks electrical.SIMOPS:PJSM for displacement from FIW to 8.9 ppg OBM.,M-28 wellhead pressures; 13-318"X9-5/8"=400 psi,16"X13-3/8"=260 psi,26"X16"=325 psi,31"X26"=140 psi. Losses for 24 hrs 0 bbls. • • 5/1/2017 Trouble shoot drawworks SCR's,traction motors will not go into assignment.SIMOPS:service air tuggers,Canrig tech reroute cables to drillers console,install air slips foot pedal actuator,change out screens on shakers,&Canrig mudlogger rig up logging system.,Trouble shoot drawworks SCR's;diagnose traction motor air sensor switch&resolve.,PJSM,TIH f/8397-8545'MD, PU 275K,SO 185K,ROT 225K.Displace well from FIW to 8.9 ppg OBM,pump 23 bbls spacer&580bbls of OBM at 500 gpm, ICP 1400 psi,FCP 1660 psi,40 rpm intial Tq 15K/final Tq 9K,PU 245K,SO 205K,ROT 223K.,TOH f/8545-8492' MD,racking back 1 stand.Pick up 1 single 5"DP,to space out for milling,TIH f/8492'-8519'MD,PU 245K,SO 205K.,Transfer FIW from pits to production, t- clean&pump out trip tanks of spacer/interface to dirty iso-tank,clean pits to tranfer OBM from uprights for drilling ops.,Service rig equipment grease drawworks.SIMOPS ship FIW to production.,Clean pits of FIW debris for OBM&ship FIW to production.,Transfer OBM from uprights to mud pits.,TIH to 8550'MD&obtain parameters PU 245K,SO 205K, ROT 220K,500 gpm,1680 psi,80 rpm,Tq 9K.Fill lines&shaker pits.Obtain at 8549'MD,7053'TVD, MW 8.9 PPG SPR#1 ©30=160psi,@ 40=200psi;#2 @ 30=150psi,@40=200psi.,Mill window ft 8549'-8554'MD,PU 245K,SO 205K, ROT 220K,500 gpm, 1670 psi,100 rpm,Tq 11-15K, FO 73%,catching metal swarf at shakers.,M-28 wellhead pressures;13-3/8"X9-518"=400 psi,16"X13-3/8"=260 psi,26"X16"= 340 psi,31"X26"=145 psi.Losses for 24 hrs 0 bbls. 5/2/2017 Mill window f/8554'-8586'MD,PU 245K,SO 205K,ROT 220K,500 gpm, 1670 psi, 100 rpm,Tq 11-15K, recovering metal cuttings at shakers.,CBU clean, drift window with mills,pumps on&off>5k drag,TOW-8550',BOW-8567'.,Preform FIT test t/EMW 12.6 PPG, Pump 5.4 bbls,final pressure after 5 min 1335psi,bleed off capture 5.6 bbls.,Cont.mill formation f/8586't/8606',up wt 245k,do wt 200k,rot wt 217k,tq off 11k,on 11-15k,500 GPM,1700psi,max gas 200 units.,CBU clean,POOH U8545',condition mud,500 gpm, 1680 psi.,Service TD,POOH t/628',tq check every connection t/29k.,Stand back HWDP, check mill gauge,good,ltd BHA.,Clean&clear rig floor,service rig.,P/U mule shoe,rih p/u 5"dp.,M-28 wellhead pressures; 13-3/8"X9-5/8"=440 psi, 16"X13- 3/8"=260 psi,26"X16"=340 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls. • 11110 Hilcorp Energy Company Composite Report Well Name: MRF M-28RD Field: County/State: CIO,Alaska (LAT/LONG): :vation(RKB): API#: 50-733-20414-01-00 Spud Date: Job Name: 1710804D M-28RD Drilling Contractor AFE#: AFE$: IffiliiiiiiiiiINIMMINNEsampsommimimmossomentigtooigiivonammommensmonniliiiiimuman . ::..::.:.:.. w MM 5/3/2017 RIH P/U 5"19.5#drill pipe,t/3790',tq connections t/29k.;Hang blocks,cut&slip 43'drill line.;Service rig.;POOH f/3790',stand back 5"DP.;Clean&clear floor,prep t/P/U BHA.;P/U BHA#4.Make up 8.5"PDC bit,Geo-Pilot assy w/stab,DM collar,in line stab, DGR,EWR,PWD,HCIM,ALD w/stab&CTN,TM collar,float sub,flex collar,;m/u MWD upload tools and shallow test same,good, PJSM,&load source,cont.p/u 2-flex collars,6-HWDP,hyd jars w/bumper sub,11-HWDP, BHA total=754.55'.;TIH on 5"dp,1/2649',up wt, 136k,dn wt 128k.;Fill pipe,Break in Geo-pilot as per DD,set block height f/auto driller.;Cont. TIH t/6439',filling every 20 stands. 5/4/2017 Cont RIH With Sperry GEO-Pilot Assembly#4 F/6,439(Fill Point)To 8,525.;Establish Circulation at 8,525(25'Above Top Of Window)-Cir to Shear OBM- PU 255,SO 205,R 223,30rpm=11k Torque, 450gpm=1,970psi,SLOW Pump Rate with 9ppg Mud 54 Vis#1 40spm=350psi.;RIH To Btm Of Window Without Trouble-Ream Down to 8,606 Without Trouble-Drill 8 1/2"Hole F/8,606 to 8,635(29')With Slow Rotary(30)And 10 to 15K Bit Weight- Working LWD Tools Through Window.;Cont Drilling With Slow Rotary&Lighter Bit Weights Working LWD Tools Through Window Down To 8,770(Tools Clear)-Started Increasing RPM&Bit Weight to 110rpm 15 to 20k WOB 440gpm 1,860psi.;Drilled With Rotary Steerable to 8820md(7272tvd)-PU 260,SO 204,R 230,110rpm, 15 to 18k torque,440gpm 1,860psi.;Cont Drilling With Rotary Steerable F/8,820'-1/9183',up wt 270k,dn wt 207k,rot wt 237k,440 GPM,1930psi,120 rpm, tq on 16k,tq off 13k,ECD=9.6.;Cont Drilling With Rotary Steerable F/9183't/9611'up wt 289k,dn wt 212k,rot wt 246k,440 GPM, 1950psi,120 rpm, tq on 19k,tq off 14k,ECD=9.6 wob=18-22.;M-28RD wellhead pressures;13-3/8"X9-5/8"=460 psi,16"X13-3/8"=260 psi,26"X16"=330 psi, 31"X26"=145 psi.Losses for 24 hrs 0 bbls.Distance to plan=16.83', 1.48'High,16.76'Ieft;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:0.37 lbs Total:774 lbs 5/5/2017 Drilling 8 1/2"With Geo-Piliot Rotary Steerable F/9,598 to 10,036(8,452tvd)-PU 303,SO 220, R 255-466gpm(11bbI/min)2,180psi-120rpm 18k torque.;Cir&Condition Mud For Wiper Trip-Circulated Btms Up 2x-End Of First Cir The Fines Cleaned Up Quite a Bit-Had A Good Abount of 1/8"Cuttings Coming Across-Started Cleaning Up With 75%Of;Second Btms Up Pumped 9.1 ppg 56vis out-9ppg 54 vis in.;POH On Elevators From 10,036 To 9,173- Pulled Well With Spotty Overpulls Of 10 to 20K Which we would Slide By-Did Not Have to Break It Back Down-Took Good Hole Fill With 8Bbl For 9 Stnds.;RIH to 9,437 and Took A Check Shot Survey 10 deg 349.64 Az-Cont RIH to 9,942-Trip In Was Clean-Kelly Up And Safety Ream From 9,942 to 10,036.;Drilling 8 1/2"With Geo-Piliot Rotary Steerable F/ 10,036 to 10,146-Drilled The Coal 20 F/10,165 DPM to 10,170 DPM.;Cont Directional Drilling T/10,245-Drilled the 39 Coal to 10,260 DPM -Cont To Have Ratty Drilling Down to 10 324.;Cont.Directional drilling f/10324't/10548',up wt 320k,dn wt 225, rot wt 265,465 GPM,2190psi,135 RPM,tq off 16k,on 20k.;Cont.Directional drilling f/10548',t/10604'up wt 320k,dn wt 225,tot wt 265,465 GPM,2190psi, 135 RPM,tq off 16k,on 20k,(hit hard formation @10558',10572',10590').;Cont.Directional drilling f/10604'-T110772' up wt 325k,dn wt 225,rot wt 266,465 GPM,2190psi,135 RPM,tq off 16k,on 20k.;M-28RD wellhead pressures;13-3/8"X9-5/8"=460 psi,16"X13-3/8"=260 psi,26"X16"=330 psi,31"X26"=145 psi.Losses for 24 hrs X bbls.Distance to plan=28.22',15.05 low,23.88'left;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:53 lbs Total:827 lbs 516/2017 Cont Dir Drilling W/Rotary Steerable Fl 10,772 to 10,928(26'/hr Pipe In Ground)-PU 330,SO 237,R 270-455gpm(10.8Bbl)at 2,025psi-100RPM 20K Tor With 20k WOB-SPR @40spm#1 =420psi#2=410;Cont Dir DrI W/RS F/10,928 T/11,121 (32'/hr PIG)-PU 350,SO 225,R 270-2,243psi @ 462gpm (11 Bbl/min)-20 to 22K Tor at 120rpm 20 to 25k WOB.;Cont Dir Dr!W/RS F/11,121', 1111272'-PU 3400,SO 225,R 270-2,243psi @ 445gpm,2010psi- 18-21 k Tq at 120rpm 20 to 25k WOB.;Cont Dir Dr!W/RS F/11272',t/11295',-PU 3400,SO 225,R 270-2,243psi @ 440gpm,2000psi-18-21k Tq at 120rpm 20 to 25k WOB, changed out swab on#1 mp.;ROP stopped,worked changing parameters to get going again with no joy.;POOH t/11272',rack back stand,CBU x3 clean,rot&reciprocate F/11272-11178', 500gpm,2350psi.;POOH T/10830'.;M-28RD wellhead pressures; 13-3/8"X9-5/8"=520 psi, 16"X13- 3/8"=280 psi,26"X16"=250 psi,31"X26"=150 psi.Losses for 24 hrs X bbls.Distance to plan=38.64',38.30'low,5.12'right;Fluid loss to well today:0 bbls. Total:0 bbls Metal recovered:56 lbs Total:883 lbs 5/7/2017 Cont Trip Out F/10,830&Up Into Casing to 8,429-Pulled Well- Light(10 to 15k)Logged at 10,331, 10,271,10,245, 10,045,9885,9,828,9,689,9647(Most Of These related to Coal).;Over Pull to 25 to 30k 9,564&9,233(6 deg/100 Drop Section)-Did Not See Overpull When Pulling BHA Through Window.;Clean Rig Floor&Dry Pipe.;Cont POH To BHA-On Way Out Lost Top (22")Air Boot On Flow Nipple-Secure Same to Contain Fluid.;Stand Back HW-&Jars Pull Logging Tools High-No Sever Wear On Tools-Drop Back Down To Source-Pull Same From String&Secure-Down Load Logging Tools.;Pull Up-Checking Geo-Pilot Tool(OK)-Break Bit(Rung Out)-Set Geopilot Tool To The Side&Start Working On Flow Nipple.;Clean&clear floor,pull flow nipple,do all air boots on flow nipple&flow test,good,function test BOPE from remote drillers,good,monitor well-static.;P/U BHA#5.Make up 8.5"PDC bit,Geo-Pilot assy w/stab,DM collar,in line stab, DGR, EWR,PWD, HCIM, ALD w/stab&CTN,change out TM collar,float sub.;M/u Top Drive,plug into MWD upload tools and shallow test same,good.;PJSM,&load source,cont.p/u 3-flex collars,6-HWDP,hyd jars w/bumper sub, 11-HWDP,BHA total=754.89'.;TIH f/754't/8524',up wt 255k,dn wt 205k.;M-28RD wellhead pressures;13- 3/8"X9-5/8"=500 psi,16"X13-318"=275 psi,26"X16"=350 psi,31"X26"=150 psi.Losses for 24 hrs X bbls.Distance to plan=38.64',38.30'low,5.12' right.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:6 lbs Total:889 lbs • 5/8/2017 Cont RIH T 8,524-Fill Pipe&Establish Cir PU 265,SO 205,R 232-40 RPM=11K Tor-420gpm(10Bb1)=1,250psi-Cir Btms Up To Shear Mud Prior To Going Into Open Hole.;RIH Through Window And Open Hole To 11,178-Kelly Up -Cont RIH to 11,273 Filling Pipe-Safety Ream 11,273 to 11,296-PU 325,SO 215,R 268-100rpm=17k Torque-445gpm(10.6Bbi)2,100psi.;Trip In Was Clean With No Tight Spots Logged.;Directional Drilling With Rotary Steerable F/11,296 To 11,363 (67'-22'/hr Pipe In Ground)-Ran Light On Bit For 5Min-Then Started Working to Get Drilling-;Had Some Trouble Getting Started With High Torque And Little to No Penatration Rate-PU 325,SO 225,R 264-452gpm=2,190psi-140rpm=22K-686 Trip Gas.;Cont Dir Drilling W/RS 11,363 T/11,552(189'63/hr PIG)PU 340,SO 215,R 265-497gpm(11.8Bbl)=2,580-140rpm=22.5K.;Cont Dir Drilling W/RS 11,552 T/11,764 (212'71'/hr PIG)PU 340,SO 210,R 263,495GPM,2550PSI,TQ-22K.;Cont Dir Drilling W/RS F/11,764'T/11929',PU 348K,SO 210K,R 261K,491 GPM, 2500 PSI,140RPM,10-23K,WOB-22-25K.;Cont Dir Drilling W/RS F/11929',T/12120',PU 355K,SO 205K,R 260K,497GPM,2550 PSI,140RPM, TQ- 25K,WOB-22-25K.;Cont Dir Drilling W/RS F/12120',T/12289',PU 350K,SO 205K,R 258K,485GPM,2550 PSI, 140RPM, TQ-25K,WOB-22-25K.;Cont. Dir Drilling W/RS F/12289',t/12333', PU 350K,SO 205K, R 258K,485GPM,2550 PSI,140RPM, TQ-25K,WOB-22-25K.;M-28RD wellhead pressures; 13- 3/8"X9-5/8"=480 psi, 16"X13-3/8"=260 Psi,26"X16"=340 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls.Distance to plan=7.01'Left,2.91'High,6.38'.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:35 lbs Total:924 lbs 5/9/2017 Drilling 12,333 to 12,348(15'PIG 7.5)Cont Working to Get Penetration Rate Better-Pumped A Nut Plug/NX Lube Sweep-Recommended By Eng.;When It Hit The Bit We Started Seeing Some Torque Action Along With Better Penetration.;Cont Dir Drilling ith Rotary Steerable F/12,348 To 12,414(66'/hr PIG)-PU 345,SO 210,R 260-485gpm(11.5Bbl)2,440psi-140rpm=22k.;Cont Dir Drilling With RS 12,414 T/12,613(199'66'/hr PIG)PU 355,SO 203,R 258- 492gpm 2,550psi-140rpm 23K.;Dir Drilling With RS 12,613 U 12840(227'75'/hr PIG)-PU 365,SO 195,R 258-492gpm(11.7Bbl) 2,530psi-140rpm= 25K-Pumping 15Bbl NX Lube Walnut Sweep When Ever It Started Hanging Up.;Cont Dir Drilling W/RS 12,840 T/12,972(133'44'/hr PIG)-PU-365K,SO- 200K,ROT-260K,492 GPM,2580 PSI,140RPM,TQ-23.5K.;Cont.Dir Drilling W/RS F/12,972',T/13116', (144'48'/hr PIG)-PU-370K,SO-195K,ROT- 260K,487 GPM,2570 PSI, 140RPM,TQ-24K.;Cont Dir Drilling W/RS F/13116',T/13257' (141'47'/hr PIG)-PU-375K,SO-195K,ROT-260K,479 GPM, 2580 PSI,140RPM,TQ-24K.;Cont Dir Drilling W/RS F/13257',t/13446' (189'63'/hr PIG)-PU-377K,SO-201K, ROT-260K,483 GPM,2580 PSI,140RPM, TQ-24K.;Cont Dir Drilling W/RS F/13446',t113558' (112'37'/hr PIG)-PU-377K,SO-201K,ROT-260K,483 GPM,2580 PSI, 140RPM,TQ-24K.;M-28RD wellhead pressures;13-3/8"X9-5/8"=540 psi, 16"X13-318"=275 Psi,26"X16"=350 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls. Distance to plan=.85'.85' High,0'left/right.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:29 lbs Total:953 lbs 5/10/2017 Dir Drilling W/RS 13,541 T/13.636(95'47.5'/hr PIG)pu 375 SO 200 R 250-482gpm(11.4Bbl)2,540psi-140rpm=24k-Started Seeing a Stand Pipr Pressure Loss-Down Hole Turbin Also Slowing Down;POH Looking For Washout POH F 13,636 T/11,840-Found Wash Out On Jnt#354-Would Have Been Running 1,706'off Btm-Section TD Called While Tripping For Washout-No Clean Up Before Leaving Btm;Travel Weight Off Btm 375 to 380-Had Some Overpulls to 45k-Tight Spots Logged 13,500+13,100+12,928+12,450+12,368+12,298+12,200+11,995+11,851 -Laid Out Washed Joint12302;Cont Trip Out F/11,840 T/9,851 Some Over Pull 11,054-Started Pulling Well With No Other Siginificant Overpulls Above 11,600;RIH Slow to 12,302 Started Seeing Some Set Downs Of 10 to 20k(Travel Weight)=200k-Kelly Up And Fill Pipe While RIH to 12,408-As Soon As We Caught Pressure Slowed Pump to 2.7Bbl/Min-Packed Off;Pressure Built to 1,000psi-Lost Movement For 5 or 10 Min-Worked to Get Pipe Movement with Weights From 150 to 450-Bleed Of Pressure and Worked with 500psi to Get Cir Started-Working Rotary;With 29k Torque-Saw Some Pipe Movement at 400k then Got Some Rotary Then Got Some Pump-Worked Pipe Between 12,408 and 12,503 Slowly Increaseing Pump&Rotary;Cir 2 X Btms Up-Just Saw Fines At Shaker, circ 437gpm,2150 psi;POOH f/12408',t/9756', w/10-30k drag,wk through tight spot F/11250'-11170', run back through clean, p/u 300k,SO 205k,other tight spot noted,11850';Cont. POOH t/8429',w/no op observed coming through window,had OP 10-20k,tight spots noted,9503',9425';Break Circ.,pump 400gpm,1520psi,Sperry get PWD/ECD readings,pump 22 bbl dry job,monitor hole static.;POOH U BHA©754';Work BHA,stand back HWDP,jars,flex collars t/111';M-28RD wellhead pressures;13-318"X9-5/8"=530 psi,16"X13-3/8"=280 Psi,26"X16"=360 psi,31"X26"=140 psi.Losses for 24 hrs 0 bbls. Distance to plan=.3.15".0'High,3.15'Ieft;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:38 lbs Total:991 lbs 5/11/2017 Cont POH With BHA-Remove Sorce-Down Load Tool-Lay Down Sperry Tools-Clear Rig Floor;Pull Wear Bushing-Wash Test Plug Seat;Drain Stack To Pits;lnstall Test Plug&Tighten Lock Down Screws On Compresson Seal-;PIU Test Tool-Make Up Test Subs On Top Drive;Close Blind Rams-Change Top Rams To 7"-Rig 2" Water Line To Rig Floor To Fill Stack-Move Test Pump To Rig Floor;RIH&Engage Test Plug-Fill Stack And Riser With Water- ;Pressure Testing BOP Equipment-250psi Low&3,500psi High-AOGCC Waived Wittness(Mr.Jim Regg);R/D test jt,pull test plug,drain stack,blow down choke&kill lines,install wear bushing;P/U 8.5"c/o assembly.;TIH t15321',up wt 190,do wt 152';M-28RD wellhead pressures;13-3/8"X9-5/8"=480 psi, 16"X13• 3/8"=260 Psi,26"X16"=340 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:0 lbs Total:991 lbs 5/12/2017 Cont RIH T/8518 With Clean Out Assembly;Cir From 8518 While Slip&Cut Drilling Line 105'-Service And Derrick Survey, Bump test Gas system, good;Cont RHI-No Trouble At Window-Fill Pipe At 10,457-RIH 11,266-Fill Pipe And Cir Open Hole To Window Vol(132Bb1,1320stk)-;Cont RIH-Spot Reaming As Necessary 11,290 to 11,350+11,670 to 11,733+11,860 to 11,930+11,920 to 12,020+12,520 to 12,600+;Cont RIH F/12,600 Spot Reaming As Necessart 12,610 to 12,690+12,710 to 12,760+12,800 to 12,860+12,900 to 12,970+13,000 to 13,420 Spots In This Area Were Tight With High Torque;Spot Ream F/13,420 Down To 13,630-Some Spots In This Took High(25K)Torque And Would Cause Stall Out And Over PuII;Cir Well Clean For 7" Casing -pump 518 GPM,2200psi, Used Hig Vis+High Weight Sweep Followed By Low Vis Light Wt,50%increase in cuttings @ sweep return,mix& pump 3%lube pill,spot in ann.;Changed out saver sub,(it broke at upper connection while breaking out of stand.);POOH t/11815',w/10-20k bobbles© 13500,13169,13134,12890,12800, 12446,12358-12330,12169,11962';Unable to wk past 11815',back reamed U11770,to clean up,pulled back through clean,cont.pull working through area @ 11678';M-28RD wellhead pressures; 13-3/8"X9-5/8"=480 psi,16"X13-3/8"=260 Psi,26"X16"=340 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:26 lbs Total:1017 lbs 5/13/2017 Cont Working through Tight Spot at 11,678 945k Over Pull Cont Trip Out to 10,500 Tight Spots Logged 11,200+10,900 20 to 30k-Talked to Anc Eng& agreed to Run Back to Btm For Wiper Trip;RIH F/10,500-Tight Spot At 11,039+11,645+11,700 To 11,800-We Were Able To Work Through All Spots Without Rotation-We Did Have To Put the Pump On The Hole To Work Through the 11,700 to 11,800;Worked Through the 11,700 to 11,800 area Several Times Working to Clean it Up-Still Had 20 to 25k Overpull in spots-Once We Worked Past The 11,800 It Was Pretty Clean The Rest Of Way To Btm 13,636;Cir Around 1 High Vis 1 ppg Over Sweep-Did Get a Good Increase In Cuttings At The Shaker(Sweep Report Shows 100%)-Cir One More Btms Up- Shakers Looked Good With Only Fines Coming Across;Trip Out From 13,636 Through Open Hole And Window t/8487'-Had Some Tight Spots 13,160+ 12,970+12,528+12,360+12,125+11,961 +11,800+11,613+11,547+10,930 -None Bad-;Did Not Have To Break Back On Any Of Them-Did Make Passes Back Through To Clean Up-This Was The Best Trip We Have Seen;Break circ.pump slug,drop 3.09"drift,cont.POOH t/BHA @ 653';Stand back HWDP,1/d BHA,(recovered drift at HWDP);Clean&clear floor,r/u fill up Iine;C/O handling eq.t/run 7"Iiner;M-28RD wellhead pressures; 13-3/8"X9-5/8"=500 psi,16"X13-3/8"=260 Psi,26"X16"=335 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:00 lbs Total:1017 lbs Lt `� 5/14/2017 Make Up Shoe Track-Ck/Floats-RIH Picking Up 7"29#L-80 DWC/c Liner Fill Each Joint&Top Off Each 10Jnt-To 2,370 PU 118 SO 115;Cont.RIH p/u 7" 7"29#L-80 DWC/c Liner Fill Each Joint&Top Off Each 10Jnt t15307', (installed cent.on every jt above shoe track t/9952',86 total)verify pipe count left on deck correct.;M/U Baker liner top packer/hanger assembly as per rep. ,up wt 185k,dn wt 165k;Rlh on 5"dp t/5438',circulate liner volume @ 4 bpm,320 psi;Cont.rih @ 60 FPM,on 5"dp filling every 10 stands t/8470'up wt 240k,dn wt 185k;Circulate 1 1/2 liner/dp volume @4 Bpm,415 psi;Cont.rih @ 60 FPM, on 5"dp filling every 10 stands t/10460'up wt 295k,dn wt 210k;Circulate open hole annulus volume x2 @4 Bpm,690 psi;Cont.rih @ 60 FPM,on 5"dp filling every 10 stands t/11660'started taking weight,;Wash down,working through problem area's,f/11600' t/11850'at report time,circ.@ 4BPM,600psi;M-28RD wellhead pressures;13-3/8"X9-5/8"=480 psi, 16"X13-3/8"=260 Psi,26"X16"=325 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:12 lbs Total:1029 lbs 5/15/2017 Cont.wash down,working through problem area's,f/11850',U11977'circ.@ 4BPM,600psi,RIH w/o pumps U12734'-PU 320 SO 200;CBU open hole vol,4 BPM,425 psi;Cont.RIH t/13398',PU 370 SO,210-Establish Cir;Wash in hole t/13636',circ 4 bpm,480psi,PU 350 SO 215-Taking 10 to 15'Bites- Slowly Working Pump Up To Speed;Circulate&condition mud,stage pumps up t/5bpm, 650 psi,up wt 345k,dn wt 220k;M/u CMT head&circ line,(had / issues w/cmt head,unable to rotate swivel,wk through issue);PJSM,f/CMT job,Pressure test cmt lines,800psi low test good,had leak on high test at cmt .1A head swivel,breakdown &I/d same.reconfigure to pump job without cmt head.;PJSM f/CMT job, PT cmt lines 750&4800 GOOD,mix&pump 18 bbls of C[ Tuned spacer III mud push 12.5 ppg,mix&pump 130bbls 15.3 ppg cmt(588sx) {cD 3.3 bpm,450 psi,;while reciprocating string 350k up,220 dn,shut down, ,.L launch wiper plug,displace w/338.5 bbls calculated 9.6 ppg OBM,bump plug w/332bbls @ 21:12 Pres to 1,500psi,FCP 960psi @ 91GPM 100%returns;Cal Top Of Cement 9,852;After plug bump,pressure up t/2455psi hold as per Baker rep t/set liner hanger,slack off to verify set good,pressure up w/cmt unit t/4150psi to release setting tool-Set ZXP Packer With Rotation&;70 k Set Down Weight-Cal To Of Liner 8,300:Pick Up To Slow Rate Cir Station And Flush Liner Hanger Seal Area-Cont Picking Up To High Rate Station and 1.5 Btms Up At 542gpm 1,270psi PU 220 SO 180-Trace Cement To Surface;Flush Stand Pipe Manifold-Clear Parts From Baker Cement Head Tear Down From Rig Floor-Lay Down Pup Joints;Pull to 7,580-PU 210 SO 175;Dry Pipe at 7,580;Service Rig;Trip Out With 5"D.P.-Lay Down Liner Running Tools 5/16/2017 Finish laying down BHA.Check liner running tool to confirm ZXP set.Clear&clean rig floor of BHA&cementing equipment.;Make up running tool to a stand of 5"DP&remove wear ring.;Make up stack wash tool to a stand of 5"DP.Flush stack&test plug seating area of wellhead.;Drain stack,install test plug& RILDS. Remove 7"upper rams&install 2-7/8"X 5"VBR's.;Pick up test tools&rig up to test BOP's.;Test BOPE with 2-7/8"&5"test joints to 250/3500 psi for 5 minutes,each test charted.Test annular to 250/2500 psi for 5 min each.Gas alarm systems,flow indicator,&pit level sensors tested.;Test witnessed waived by AOGCC Rep Jim Regg.;Remove test plug,drain stack,&rig down test equipment.;lnstall wear bushing w/12.5"ID&RILDS.;Mobilize BHA 7 to rig floor. Make up clean out assembly to 105'MD.;TIH ft 105'-945'MD,singling in with 4"DP. 5/17/2017 Cont RIHWith Clean Out Assembly#7 Picking Up 4"14#S-135 HT38 D.P.To 2184'.;RIH With Clean Out Assembly#7 Picking Up 4"D.P.To 4,497-Fill Pipe.;Service Rig.;Cont RIH With Clean Out Assembly#7 To 5185 -Dbl Check Pipe Count.;Cont Picking Up 4"D.P. Fot A Total Joint Count Of 166 i(55+s) in the Hole-Total Length Of 6"Tools+4"D.P=5313(Spaced Out 20' Above Top Of Liner With A Bit Depth Of 13,593'.;Pick Up#1 9 5/8 Csng Scraper& Brush.;Cont RIH With Clean Out Assembly#7 Running 5"To 8079-Fill Pipe-Cir At 8 SPM 100psi While Taking Readings-PU 190 to 195,SO 160,R 175- Torque First Break=5K,30rpm=5K,40rpm=5 to 6k.;Run In On 5"to 8,300'(Top Of Liner)-Pick Up#2 Casing Scraper(Did Not Have Brush For This Location).;Cont RIH With Clean Out Assembly#7 Running 5"To 13556'MD Tagging Insert With 10K-Verify Pipe Tally Running 260 Joints Of 5"DP-Total Length Of Tools&DP 13557'.;Circulate&Condition At 360-450 GPM,2400-3200 PSI, Reciprocating Drill String, PU 280K,SO 195K-Observed Cement Fines At The Shakers On First Bottoms Up-Total Of 4 Bottoms Ups Pumped.;Rig Up-Test 9-5/8"Casing&7"Liner To 2500 PSI For 30 Minutes,Charted- Pumped 9.1 bbls. Bumped up pressure several times to achieve solid flat Iine.;M-28RD wellhead pressures;13-3/8"X9-5/8"=480 psi,16"X13-3/8"=260 Psi, 26"X16"=320 psi,31"X26"=150 psi. Losses for 24 hrs 0 bbls.;Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:00 lbs Total:1017 lbs 5/18/2017 Finish testing 9-5/8"casing&7"liner to 2500 psi for 30 minutes,charted.pumped 9.8 bbls,bled back 10 bbls. Pressure was bumped up twice to achieve charted flat line. RID equip.&B/D lines.;PJSM,displace well from 9.6 ppg OBM to FIW at 10 bpm=3100 psi, FCP at 10 bpm=2200 psi.Slow pumps to 6.5 bpm=850 psi to catch interface.Reciprocate w/FIW,PU 340K,SO 190K.;Clean mud system surface equipment;mud pits,shaker pits,flush all surface lines. SIMOPS hook up transfer line from IA to shipping line to Trading Bay.;TOH f/13556-8300'MD to short trip 7"scraper&brush to liner lap.Flow check well, y/j� static.;TIH f/8300'-13550'MD,SO 187K,tag insert at 13556'&pick up for circulation.;Circulate FIW surface to surface 2 times,to clean well for completion fluid.Close upper rams,pump down DP,taking returns from annulus directly to Trading Bay shipping line. PJSM,test lines to 200;&800 psi. Pump 80 bbls of Baraklean pill.Initial pump rate of 65 gpm,pump pressure 250 psi&250 psi annulus pressure.Average pump rate of 420 gpm,2300 psi pump pressure&650 psi annulus;pressure.Final pump rate 231 gpm,1060 psi pump pressure&425 psi annulus pressure.;Batch up 450 bbls completion fluid of 6%KCL with.5% CFS-520 brine lube&80 bbls Baraklean pill.;Displace FIW with completion fluid.Pump 70 bbls of Baraklean pill at 5 bpm,750 psi pump pressure&375 psi annulus pressure.Pump 805 bbls of 6%KCL w/.5%CFS-520 lube brine at 9 bpm, 1950 psi pump;pressure&625 psi annulus pressure.FCP at 9 bpm,2070 psi pump pressure&640 psi annulus pressure.Blow down&rig down lines.Monitor well,static.;M-28RD wellhead pressures;13-3/8"X9-5/8"=460 psi,16"X13- 3/6=260 Psi,26"X16"=310 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls.; Fluid loss to well today:0 bbls.Total:0 bbls Metal recovered:00 lbs Total:1017 lbs 5/19/2017 Service rig,SIMOPS hang retro-fitted lights in the derrick.;TOH f/13550'-5424'MD,PU 132K,SO 125K.Obtain parameters at 13550'MD, PU 280K,SO 220K,ROT 255K,Tq @ 30&40 rpm=I2K.;Cut&slip 110'of drill line.Service/inspect drawworks,top drive&blocks.;TOH f/5424'-48'MD,PU 66K,SO 66K.;Lay down BHA 7,clear&clean rig floor.;Mobilize&rig up SLB eline tools to rig floor.Function test tractor,good.;Run in the hole with eline tools to 11953'. Tractor in f/11956-13556'MD.Log f/13556-8300',Gamma,CCL,&CBL.;M-28RD wellhead pressures;13-3/8"X9-5/8"=460 psi, 16"X13-3/8"=260 Psi, 26"X16"=310 psi,31"X26"=150 psi.Losses for 24 hrs 0 bbls. Change AFE to 1710804C at 00:00 hrs 5-20-17. • • Hilcorp Energy Company Composite Report Well Name: MRF M-28RD Field: County/State: CIO,Alaska (LAT/LONG): Ovation(RKB): API#: 50-733-20414-01-00 Spud Date: Job Name: 1710804C M-28RD Completion Contractor N AFE rv`P1,0V AFE$: C-0 Aim biti.:;. 006 Eos>�r`r>:v?::.::.:::�.:�. * ..�::'�:...'ayy,r 0 .::. ......... .:.�...W.::..,.:. .�. 5/19/2017 Continue logging f/13556'-8300',Gamma,CCL,&CBL. Rig down SLB eline equipment.,PJSM,mobilize tools&equipment for per,gun.Pick up BHA#8 to 610'MD.,M-28RD wellhead pressures;'1' .318""X9-5/8""=440 psi,16""X13-3/8""=260 Psi,26""X16""=300 psi,31""X26""=150 psi.Losses for 24 hrs 0 bbls. Change AFE to 1710804C at 00:00 hrs 5-20-17." tp Fluid loss to well today:0 bbls.Total:0 bbls 5/20/2017 Pick up pert gun assembly ft 610'-1532'MD.Pick up&inspect firing head.,Trouble shoot firing head.Change out seal sub for the firing head.,TIH f/1532'- 13293'MD, PU 253',SO 202K.Did not observe BHA pass through liner lap. Fast fill valve closed at 9625'MD.Filled pipe every 5 stands to correct for 500 psi underbalance.,Mobilize Pollard wire line equipment&rig up same.,Run correlation log,for depth of pert gun assembly.RA tag sub at 11670'MD.Rig down wire line,Confirm wire line correlation to DP strap,need to move up hole 4'.Pick up single DP to MU to TD. PU rotating 5',setting packer.SO setting 15-20K,w/ A depth at 13291'MD&RA tag at 11662'MD.Pressure up on annulus side 2 times to 2500 psi without guns firing.Attempt to unset packer,pulled 10'&slack off rr to see that packer was still set.Attempt several times to unset packer with no success.Confer with town.,M-28RD wellhead pressures;13-3/8"X9-5/8"=460 KL, psi,16"X13-3/8"=260 Psi,26"X16"=300 psi,31"X26"=150 psi. Losses for 24 hrs 0 bbls. Fluid loss to well today:0 bbls.Total:0 bbls 5/2 TOH trying to unset packer fl 13292'-12937'MD.Packer did unset at 12937'.,TIH f/12937-13300'MD,PU 253K,SO 202K.,Space out assembly w/bull plug ` @ 13291'MD&RA tag @ 11662'MD.Attempt to set off pert gun assembly 2 times,pressuring up to 2500 psi each time on the annular side.Fill&pressure .i" j up on the drill string to 3900 psi,pert guns did not fire. Line up HES cement pump&pressure up to 4500 psi,pert guns did not fire.Tripoint observed drill string IS for detonation after pressure up.,TOH f/13291'-6714'MD,PU 150K,SO 135K.,TOH f/6714'-1448'MD, PU 75K,SO 75K.,Change out firing head,packer,PAU valve,Stop-fill valve,&inspect gun Top-shot connection.,TIH ft 1448'-3137'MD, PU 100K,SO 100K,90 fpm.,Service rig.,TIH 3137'-6713'MD,90 fpm.Install XO,continue TIH w/5"DP to 11638'MD,PU 247K,SO 205K.,M-28RD wellhead pressures;13-3/8X9-5/8=460 psi,16X13-3/8=260 Psi,26X16=300 psi, 31X26=150 psi. Losses for 24 hrs 0 bbls. Fluid loss to well today:0 bbls.Total:0 bbls 5/22/20 7 Continue TIH f/11636-13280'MD,space out to set RA tag sub on depth at 11481'MD.,Rig up wire line&run correlation logs.Need to move RA tag sub up 8' to be on depth at 11474'MD. Rig down wire line.,Space out&set packer w/20K down,bull plug at 13291'MD,&RA tag sub at 11474'MD.Line up& pressure up on the annular side_puns fired at 1050 psi.Monitor drill string,observe very slight flow.Attempt to release packer 2 times pulling 15K over.Below 'ky'Ails. packer psi transfer tube opened,lined up to circulate through the choke.,Circulate through the drill string taking returns through the gas buster.Stage up pump to 4.5 bpm,350 psi,pumped 625 bbls.Dynamic loss rate 36 bph,initial loss of 25 bbls at start.Monitor well.,Open upper rams&work drill string to ensure packer unset, 13290'-13270'&back,PU 270K,SO 215K.,Circulate conventionally staging up pump 5-8 bpm,350-880 psi,pump 12 bbls to get returns. Observed increase in flow w/crude&gas at 530 bbls into circulation.Pump 1262 bbls for 2.5 BU,dynamic loss rate—36 bph.,Lay down space out joints&pup ft 13290'-13242'MD.,Monitor well to establish static loss rate,circulating across the top.Initial 10 min=19 bph,20 min=15 bph,30=12 bph.SIMOPS change out ST-80 dies&grease drawworks.,Circulate surface to surface staging up the pump 4-8 bpm,230-850 psi,pumped 712 bbls,50 bbls loss during circulation. SCR's @ 13240'MD,8.6 ppg;#1 @ 30=90,@ 40=230;#2 @ 30=100 @ 40=240 psi.,TOH racking back 5"DP f/13240'-8040'MD,PU 185K,SO 155K.,Service top drive&blocks.,TOH racking back 5"DP f/8040'-6650'MD,PU 165K,SO 133K.Lay down XO&change elevators to 4".,TOH laying down 4"DP f/6650'-4150'MD,PU 126K,SO 98K.,M-28RD wellhead pressures;13-3/8X9-5/8=460 psi,16X13-3/8=260 Psi,26X16=300 psi,31X26=150 psi. Fluid loss to well today:291 bbls.Total:291 bbls 5/23/2017 TOH laying down 4"DP f/4150'-1501'MD PU 82K,SO 77K.,Rig up handling equipment for TCP.Make up safety joint for TCP&lay down packer.Lay down �4 assembly to surface.All shots fired on TCP.,Rig down handling equipment for TCP.Clear&clean rig floor.Lay down safety joint.,Remove wear bushing.,Mobilize WFT handling equipment to rig floor.Stage Summit ESP equipment on rig floor.Hang sheaves with cables in derrick.,Make up ESP assembly;Anode/Centralizer,Gauge,Motor,Seals 1 &2,and Gas Sep.to 56'MD.,M-28RD wellhead pressures; 13-3/8X9-5/8=460 psi,16X13-3/8=260 Psi, 26X16=300 psi,31X26=150 psi. Fluid loss to well today:231 bbls.Total:522 bbls. 5/24/2017 Finish picking up ESP assembly 54'-123'MD;3 pumps 400 series,discharge head&ported pressure sub. Rig down&clear Summit tools&equipment from floor.,TIH w/42 joints of 2-7/8",6.4#,8RD EUE, L80 tubing f/123'-1462'MD,check ESP cable every 1000',SO 77K MU Tq 2030 fUlbs.Install cannon clamps every joint.,Service rig,grease drawworks,inspect tools&equipment.,TIH to joint 111 of 2-7/8",6.4#,8RD EUE,L80 tubing f/1462'-3612'MD,check ESP cable every 1000',SO 92K,MU Tq 2030 ft/lbs. Install cannon clamps every joint to 109,then every other joint.,Trouble shoot skate,with no success. Carrier stuck in the up position.Manually lower carrier back to catwalk.SIMOPS clean out gasbuster,change out derrick light,clean OBM from mud discharge trough.,Rig up&set floor up,to pick up tubing from catwalk with tugger.,TIH to joint 173 of 2-7/8",6.4#,8RD EUE, L80 tubing f/3612'-5543'MD,check ESP cable every 1000',SO 99K,MU Tq 2030 ft/lbs.Install cannon clamps every other joint.,Splice ESP cable.SIMOPS change out derrick lights.,M-28RD wellhead pressures; 13-318X9-5/8=460 psi,16X13-3/8=260 Psi,26X16=300 psi,31X26=150 psi. Fluid loss to well today:216 bbls.Total:738 bbls. • • 5/25/2017 Finish making first splice©5543'MD,test good.,TIH to joint 270 of 2-7/8",6.4#,8RD EUE,L80 tubing f/5543'-8564'MD,check ESP cable every 1000',SO 110K,MU Tq 2030 ft/lbs.Install cannon clamps every other joint.Install 4'clamp over first splice on joint 179.Install 4'clamp over old cable splice on joint 263.,TIH to joint 354 of 2-7/8",6.4#,8RD EUE,L80 tubing f/8564'-11179'MD,check ESP cable every 1000',SO 125K,MU Tq 2030 fUlbs. Install cannon clamps every other joint.,Pick up Tripoint 9-5/8"Hydroset II ESP packer to 11259'MD,SO 125K,perform ESP splice&tie in vent Iines.,TIH to joint 359 of 2- 7/8",6.4#,8RD EUE,L80 tubing f/11259'-11373'MD.Tie in vent lines to SSSV,SO 125K,cannon clamp every joint.,TIH to joint 370 of 2-7/8",6.4#,8RD EUE,L80 tubing f/11373'-11722'MD,SO 125K,MU Tq 2030 fUlbs. Install cannon clamps everyjoint.,Make up Cameron tubing hanger 13-5/8",4-1/2"IBT box X 4-1/2"IBT pin,with XO 4-1/2"IBT box X 2-7/8"EUE pin.Orient offset per NOS Rep.Make up 1 joint of 4-1/2"IBT-M landing joint.,Terminate ESP from spooler&install penetrator per Summit.,Slack off to land hanger,with hanger taking weight at the annular.Work several times to push hanger through annular.,M-28RD wellhead pressures;13-3/8X9-5/8=460 psi, 16X13-3/8=260 Psi,26X16=300 psi,31X26=150 psi. Fluid loss to well today:184 bbls. Total:922 bbls. 5/26/2017 Work hanger through annular&continue down,picking up 1-30'joint,6'&10'pups for landing joint.Orient for hanger alignment pins& land hanger with SO 125K(block weight 60K).Total cross collar clamps 249ea,equipment clamps 20ea,4'splice clamps 3ea,stainless steel band clamps 22ea.,Rig down ESP () cable,Cap line,sheaves,&Summit equipment from rig floor.Drop ball&rod.Rig up Pollard wire line equipment.,Line up&fluid pack tubing&annulus. Pressure up tubing,observe packer set at 900 psi.Continue to pressure up to 3925 psi&hold for 30 minutes,bleed off pressure.,Line up to pump down the IA k �/ 1-to test packer&hanger.Pressure up to 1800 psi&hold for 30 minutes,cftarted.Bleed back 1.1 bbls,blow down lines.Remove test pump from rig floor.,Rig up Old Pollard wire line,lubricator,&sheaves.RIH to 613'&pull RHCP prong to surface. RIH to 617'&pull plug body to surface.Rig down wire line equipment. W Summit conduct final check on ESP cable.,Back out 4-1/2"IBT-M landing joint&lay down.,NOS wellhead tech install 4",Type H BPV.Rack back T-bar in derrick&secure.,Rig down WFT tongs&handling equipment.Clear&clean rig floor.,Nipple down BOPE.Clean fluid&debris from flow box.Remove flow nipple&flow box.Disconnect Koomey lines,choke&kill from stack.Pick BOP stack,stump back&secure on pedestal.Remove upper&lower high pressure risers.,NOS wellhead tech clean up hanger profile&penetrator. Pick tree&change out tubing head adapter. Lower tree to well bay&install SS actuator bonnet.Nipple up tree to well head.Nipple up flow line.Test void to 250/5000 psi for 15 min.Remove BPV install TWC.Test tree to 5000 psi for 5 min. Remove TWC.,M-28RD wellhead pressures; 13-3/8X9-5/8=460 psi,16X13-3/8=260 Psi,26X16=310 psi,31X26=150 psi. Fluid loss to well today:51 bbls. Total:973 bbls. Release rig at 06:00 hrs. • • Hilcorp Alaska, LLC p A McArthur River Field Steelhead M-28RD 50-733-20414-01-00 Sperry Drilling Definitive Survey Report 17 May, 2017 HALLIBURTON Sperry Drilling • 1. Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Project McArthur River Field Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor I Well Trading Bay Unit M-28RD Well Position +N/-S 0.00 usft Northing: 2,499,500.32 usft Latitude: 60°49'54.951 N +E/-W 0.00 usft Easting: 214,174.37 usft Longitude: 151°36'6.756 W Position Uncertainty 0.00 usft Wellhead Elevation: 160.00 usft Water Depth: 187.00 usft Wellbore M-28RD Magnetics Model Name * Sample Date Declination Dip Angle Field Strength 4 ?ter' (It; °) () V (nT) BGGM2016 4/27/2017 16.08 73.72 55,428 Design M-28RD Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,530.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 18.02 Survey Program Date 5/15/2017 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 25.00 8,461.00 SDI Gyro M-28(M-28) NSG-CT_D/P Continuous north-seeking gyro in drillpipe 04/28/2017 8,530.00 8,530.00 TBU M-28(M-28) NSG_WL North seeking gyro on wireline 01/28/1990 8,550.00 8,773.69 M-28RD(M-28RD) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 04/27/2017 8,868.60 13,508.55 MWD+SC+sag(M-28RD) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 05/05/2017 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 0.00 0.00 0.00 0.00 -160.00 0.00 0.00 2,499,500.32 214,174.37 0.00 0.00 UNDEFINED 25.00 0.12 333.98 25.00 -135.00 0.02 -0.01 2,499,500.34 214,174.36 0.48 0.02 NSG-CT_D/P(1) 50.00 0.24 333.98 50.00 -110.00 0.09 -0.05 2,499,500.41 214,174.33 0.48 0.08 NSG-CT_D/P(1) 75.00 0.19 288.99 75.00 -85.00 0.15 -0.11 2,499,500.47 214,174.27 0.68 0.11 NSG-CT_D/P(1) 100,00 0.33 132.26 100.00 -60.00 0.12 -0.09 2,499,500.44 214,174.28 2.04 0.08 NSG-CT_D/P(1) 125.00 0.27 107.13 125.00 -35.00 0.05 0.02 2,499,500.37 214,174.39 0.57 0.06 NSG-CT_D/P(1) 150.00 0.18 52.60 150.00 -10.00 0.06 0.10 2,499,500.37 214,174.48 0.88 0.09 NSG-CT_D/P(1) 175.00 0.03 201.83 175.00 15.00 0.08 0.13 2,499,500.39 214,174.51 0.83 0.12 NSG-CT_D/P(1) 200.00 0.06 274.30 200.00 40.00 0.07 0.12 2,499,500.39 214,174.49 0.23 0.11 NSG-CT_D/P(1) 225.00 0.38 157.77 225.00 65.00 0.00 0.13 2,499,500.31 214,174.51 1.64 0.04 NSG-CT_D/P(1) 250.00 0.12 47.75 250.00 90.00 -0.06 0.19 2,499,500.25 214,174.56 1.74 0.00 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 2 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 275.00 0.27 61.33 275.00 115.00 -0.02 0.26 2,499,500.29 214,174.63 0.62 0.06 NSG-CT_D/P(1) 300.00 0.19 74.03 300.00 140.00 0.02 0.35 2,499,500.33 214,174.72 0.38 0.13 NSG-CT_D/P(1) 325.00 0.24 132.87 325.00 165.00 0.00 0.43 2,499,500.30 214,174.80 0.86 0.13 NSG-CT_D/P(1) 350.00 0.67 114.21 350.00 190.00 -0.10 0.60 2,499,500.21 214,174.97 1.80 0.09 NSG-CT_D/P(1) 375.00 0.54 84.48 375.00 215.00 -0.14 0.85 2,499,500.15 214,175.22 1.34 0.12 NSG-CT_D/P(1) 400.00 0.68 98.16 399.99 239.99 -0.15 1.11 2,499,500.13 214,175.48 0.80 0.20 NSG-CT_D/P(1) 425.00 0.82 102.19 424.99 264.99 -0.21 1.43 2,499,500.07 214,175.80 0.60 0.24 NSG-CT_D/P(1) 450.00 1.04 106.91 449.99 289.99 -0.32 1.83 2,499,499.95 214,176.19 0.93 0.26 NSG-CT_D/P(1) 475.00 0.96 105.78 474.99 314.99 -0.44 2.24 2,499,499.82 214,176.61 0.33 0.28 NSG-CT_D/P(1) 500.00 1.32 108.72 499.98 339.98 -0.59 2.72 2,499,499.66 214,177.08 1.46 0.28 NSG-CT_D/P(1) 525.00 1.35 105.44 524.97 364.97 -0.76 3.28 2,499,499.48 214,177.63 0.33 0.29 NSG-CT_D/P(1) 550.00 1.52 101.52 549.97 389.97 -0.90 3.88 2,499,499.32 214,178.24 0.78 0.34 NSG-CT_D/P(1) 575.00 1.63 105.12 574.96 414.96 -1.06 4.55 2,499,499.14 214,178.90 0.59 0.40 NSG-CT_D/P(1) 600.00 1.70 100.56 599.95 439.95 -1.22 5.26 2,499,498.96 214,179.60 0.60 0.46 NSG-CT_D/P(1) 625.00 1.84 91.18 624.93 464.93 -1.30 6.03 2,499,498.87 214,180.37 1.29 0.63 NSG-CT_D/P(1) 650.00 2.08 88.88 649.92 489.92 -1.30 6.88 2,499,498.85 214,181.22 1.01 0.89 NSG-CT_D/P(1) 675.00 2.23 82.56 674.90 514.90 -1.23 7.82 2,499,498.90 214,182.16 1.12 1.25 NSG-CT_D/P(1) 700.00 2.24 82.63 699.88 539.88 -1.10 8.78 2,499,499.00 214,183.13 0.04 1.67 NSG-CT_D/P(1) 725.00 2.00 84.05 724.87 564.87 -0.99 9.70 2,499,499.08 214,184.05 0.98 2.06 NSG-CT_D/P(1) 750.00 2.13 87.13 749.85 589.85 -0.93 10.60 2,499,499.13 214,184.95 0.68 2.40 NSG-CT_D/P(1) 775.00 2.07 90.30 774.83 614.83 -0.91 11.52 2,499,499,13 214,185.86 0.52 2.70 NSG-CT_D/P(1) 800.00 2.13 82.44 799.82 639.82 -0.85 12.43 2,499,499.17 214,186.78 1.18 3.04 NSG-CT_D/P(1) 825.00 1.99 74.96 824.80 664.80 -0.67 13.31 2,499,499.32 214,187.66 1.21 3.48 NSG-CT_D/P(1) 850.00 1.87 83.70 849.79 689.79 -0.52 14.13 2,499,499.46 214,188.49 1.27 3.88 NSG-CT_D/P(1) 875.00 1.87 72.29 874.77 714.77 -0.35 14.93 2,499,499.60 214,189.29 1.49 4.29 NSG-CT_D/P(1) 900.00 1.94 74.92 899.76 739.76 -0.11 15.72 2,499,499.82 214,190.09 0.45 4.76 NSG-CT_D/P(1) 925.00 2.08 75.35 924.74 764.74 0.11 16.57 2,499,500.02 214,190.94 0.56 5.23 NSG-CT_D/P(1) 950.00 2.16 65.27 949.73 789.73 0.42 17.44 2,499,500.31 214,191.82 1.52 5.80 NSG-CT_D/P(1) 975.00 2.31 64.19 974.71 814.71 0.84 18.32 2,499,500.71 214,192.71 0.62 6.47 NSG-CT_D/P(1) 1,000.00 2.64 61.49 999.68 839.68 1.33 19.28 2,499,501.18 214,193.68 1.40 7.23 NSG-CT_D/P(1) 1,025.00 2.93 55.88 1,024.65 864.65 1.97 20.31 2,499,501.79 214,194.73 1.59 8.16 NSG-CT_D/P(1) 1,050.00 2.77 59.01 1,049.62 889.62 2.64 21.36 2,499,502.43 214,195.79 0.89 9.12 NSG-CT_D/P(1) 1,075.00 2.87 56.09 1,074.59 914.59 3.30 22.40 2,499,503.07 214,196.85 0.70 10.06 NSG-CT_D/P(1) 1,100.00 2.91 50.07 1,099.56 939.56 4.05 23.40 2,499,503.80 214,197.87 1.22 11.09 NSG-CT_D/P(1) 1,125.00 2.97 43.09 1,124.53 964.53 4.93 24.33 2,499,504.65 214,198.82 1.45 12.22 NSG-CT_D/P(1) 1,150.00 3.07 34.42 1,149.49 989.49 5.96 25.15 2,499,505.66 214,199.67 1.87 13.45 NSG-CT_D/P(1) 1,175.00 3.29 27.44 1,174.46 1,014.46 7.15 25.86 2,499,506.83 214,200.40 1.78 14.80 NSG-CT_D/P(1) 1,200.00 3.69 22.51 1,199.41 1,039.41 8.53 26.50 2,499,508.19 214,201.08 2.00 16.31 NSG-CT_D/P(1) 1,225.00 4.26 16.60 1,224.35 1,064.35 10.16 27.07 2,499,509.81 214,201.69 2.80 18.04 NSG-CT_D/P(1) 1,250.00 4.84 12.02 1,249.27 1,089.27 12.08 27.56 2,499,511.72 214,202.22 2.74 20.02 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 3 COMPASS 5000.1 Build 81 0 • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,275.00 5.62 9.95 1,274.17 1,114.17 14.32 27.99 2,499,513.95 214,202.71 3.21 22.28 NSG-CT_D/P(1) 1,300.00 6.50 9.42 1,299.03 1,139.03 16.92 28.43 2,499,516.54 214,203.21 3.53 24.89 NSG-CT_D/P(1) 1,325.00 7.10 9.83 1,323.85 1,163.85 19.84 28.93 2,499,519.44 214,203.78 2.41 27.82 NSG-CT_D/P(1) 1,350.00 7.86 11.44 1,348.64 1,188.64 23.04 29.53 2,499,522.63 214,204.46 3.15 31.04 NSG-CT_D/P(1) 1,375.00 8.46 11.80 1,373.38 1,213.38 26.51 30.25 2,499,526.08 214,205.26 2.41 34.57 NSG-CT_D/P(1) 1,400.00 9.19 12.53 1,398.09 1,238.09 30.26 31.06 2,499,529.81 214,206.16 2.95 38.39 NSG-CT_D/P(1) 1,425.00 9.53 12.42 1,422.75 1,262.75 34.23 31.94 2,499,533.76 214,207.14 1.36 42.43 NSG-CT_D/P(1) 1,450.00 9.95 12.34 1,447.39 1,287.39 38.36 32.84 2,499,537.87 214,208.14 1.68 46.64 NSG-CT_D/P(1) 1,475.00 10.10 12.37 1,472.01 1,312.01 42.61 33.77 2,499,542.09 214,209.18 0.60 50.97 NSG-CT_D/P(1) 1,500.00 10.64 12.03 1,496.60 1,336.60 47.01 34.72 2,499,546.47 214,210.24 2.17 55.45 NSG-CT_D/P(1) 1,525.00 11.33 12.51 1,521.15 1,361.15 51.67 35.74 2,499,551.10 214,211.36 2.78 60.19 NSG-CT_D/P(1) 1,550.00 12.50 12.68 1,545.61 1,385.61 56.70 36.86 2,499,556.10 214,212.61 4.68 65.33 NSG-CT_D/P(1) 1,575.00 13.60 13.07 1,569.96 1,409.96 62.21 38.12 2,499,561.57 214,214.00 4.41 70.95 NSG-CT_D/P(1) 1,600.00 14.57 13.87 1,594.21 1,434.21 68.12 39.54 2,499,567.45 214,215.57 3.96 77.01 NSG-CT_D/P(1) 1,625.00 15.55 14.56 1,618.35 1,458.35 74.42 41.14 2,499,573.71 214,217.32 3.98 83.50 NSG-CT_D/P(1) 1,650.00 16.48 15.11 1,642.38 1,482.38 81.09 42.90 2,499,580.33 214,219.24 3.77 90.38 NSG-CT_D/P(1) 1,675.00 17.23 15.86 1,666.31 1,506.31 88.07 44.84 2,499,587.27 214,221.35 3.12 97.62 NSG-CT_D/P(1) 1,700.00 17.90 16.77 1,690.14 1,530.14 95.31 46.96 2,499,594.45 214,223.65 ' 2.90 105.16 NSG-CT_D/P(1) 1,725.00 18.49 17.38 1,713.89 1,553.89 102.77 49.25 2,499,601.86 214,226.12 2.48 112.97 NSG-CT_D/P(1) 1,750.00 19.12 18.31 1,737.56 1,577.56 110.44 51.72 2,499,609.46 214,228.78 2.79 121.03 NSG-CT_D/P(1) 1,775.00 20.01 19.44 1,761.11 1,601.11 118.37 54.43 2,499,617.32 214,231.68 3.87 129.40 NSG-CT_D/P(1) 1,800.00 20.81 20.18 1,784.54 1,624.54 126.57 57.39 2,499,625.44 214,234.84 3.36 138.11 NSG-CT_D/P(1) 1,825.00 21.69 20.58 1,807.84 1,647.84 135.06 60.55 2,499,633.86 214,238.20 3.57 147.17 NSG-CT_D/P(1) 1,850.00 22.45 20.87 1,831.01 1,671.01 143.85 63.87 2,499,642.56 214,241.74 3.07 156.55 NSG-CT_D/P(1) 1,875.00 22.94 20.67 1,854.07 1,694.07 152.86 67.29 2,499,651.49 214,245.38 1.98 166.18 NSG-CT_D/P(1) 1,900.00 23.29 20.58 1,877.07 1,717.07 162.05 70.75 2,499,660.59 214,249.06 1.41 175.99 NSG-CT_D/P(1) 1,925.00 23.94 20.75 1,899.97 1,739.97 171.42 74.28 2,499,669.87 214,252.82 2.61 185.99 NSG-CT_D/P(1) 1,950.00 24.51 21.11 1,922.77 1,762.77 181.00 77.95 2,499,679.36 214,256.72 2.36 196.24 NSG-CT_D/P(1) 1,975.00 24.61 21.23 1,945.51 1,785.51 190.69 81.70 2,499,688.95 214,260.71 0.45 206.61 NSG-CT_D/P(1) 2,000.00 24.88 21.08 1,968.21 1,808.21 200.45 85.48 2,499,698.62 214,264.72 1.11 217.06 NSG-CT_D/P(1) 2,025.00 25.23 20.98 1,990.86 1,830.86 210.33 89.28 2,499,708.40 214,268.76 1.41 227.63 NSG-CT_D/P(1) 2,050.00 25.88 20.88 2,013.42 1,853.42 220.40 93.13 2,499,718.38 214,272.86 2.61 238.40 NSG-CT_D/P(1) 2,075.00 26.76 20.68 2,035.82 1,875.82 230.77 97.06 2,499,728.64 214,277.04 3.54 249.47 NSG-CT_D/P(1) 2,100.00 27.99 20.54 2,058.02 1,898.02 241.53 101.11 2,499,739.30 214,281.35 4.93 260.96 NSG-CT_D/P(1) 2,125.00 29.10 20.54 2,079.98 1,919.98 252.71 105.30 2,499,750.38 214,285.81 4.44 272.89 NSG-CT_D/P(1) 2,150.00 30.14 20.89 2,101.72 1,941.72 264.27 109.67 2,499,761.83 214,290.46 4.22 285.23 NSG-CT_D/P(1) 2,175.00 31.21 21.22 2,123.22 1,963.22 276.17 114.25 2,499,773.62 214,295.34 4.33 297.97 NSG-CT_D/P(1) 2,200.00 31.85 21.61 2,144.53 1,984.53 288.34 119.03 2,499,785.67 214,300.41 2.69 311.02 NSG-CT_D/P(1) 2,225.00 32.74 21.83 2,165.66 2,005.66 300.75 123.97 2,499,797.95 214,305.65 3.59 324.35 NSG-CT_D/P(1) 2,250.00 33.66 22.27 2,186.58 2,026.58 313.44 129.11 2,499,810.51 214,311.10 3.80 338.00 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 4 COMPASS 5000.1 Build 81 • 0 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 2,275.00 34.30 22.49 2,207.31 2,047.31 326.36 134.43 2,499,823.29 214,316.73 2.61 351.94 NSG-CT_D/P(1) ' 2,300.00 34.96 22.58 2,227.88 2,067.88 339.48 139.88 2,499,836.28 214,322.50 2.65 366.10 NSG-CT_D/P(1) 2,325.00 35.65 22.77 2,248.28 2,088.28 352.81 145.45 2,499,849.47 - 5 5 214 328.39 2.79 380.50 NSG CT D/P(1) 2,350.00 36.48 23.03 2,268.49 2,108.49 366.37 151.17 2,499,862.88 214,334.45 3.38 395.16 NSG-CT_D/P(1) 2,375.00 37.53 23.33 2,288.46 2,128.46 380.20 157.10 2,499,876.57 214,340.71 4.26 410.15 NSG-CT_D/P(1) 2,400.00 38.01 23.63 2,308.22 2,148.22 394.25 163.20 2,499,890.46 214,347.15 2.06 425.39 NSG-CT_D/P(1) 2,425.00 38.54 23.78 2,327.84 2,167.84 408.42 169.43 2,499,904.48 214,353.72 2.15 440.80 NSG-CT_D/P(1) 2,450.00 39.09 23.92 2,347.32 2,187.32 422.76 175.76 2,499,918.65 214,360.40 2.23 456.39 NSG-CT_D/P(1) 2,475.00 39.24 23.94 2,366.71 2,206.71 437.19 182.17 2,499,932.92 214,367.16 0.60 472.10 NSG-CT_D/P(1) 2,500.00 39.30 23.96 2,386.06 2,226.06 451.65 188.59 2,499,947.22 214,373.93 0.25 487.84 NSG-CT_D/P(1) 2,525.00 39.45 24.08 2,405.39 2,245.39 466.14 195.05 2,499,961.55 214,380.74 0.67 503.61 NSG-CT_D/P(1) 2,550.00 39.82 24.10 2,424.64 2,264.64 480.69 201.56 2,499,975.94 214,387.60 1.48 519.47 NSG-CT_D/P(1) 2,575.00 40.01 24.11 2,443.81 2,283.81 495.34 208.11 2,499,990.42 214,394.51 0.76 535.42 NSG-CT_D/P(1) 2,600.00 39.84 24.03 2,462.99 2,302.99 509.99 214.65 2,500,004.91 214,401.41 0.71 551.37 NSG-CT_13/P(1) 2,625.00 39.73 24.01 2,482.20 2,322.20 524.60 221.16 2,500,019.35 214,408.28 0.44 567.28 NSG-CT_D/P(1) 2,650.00 39.64 24.10 2,501.44 2,341.44 539.18 227.67 2,500,033.77 214,415.14 0.43 583.16 NSG-CT_D/P(1) 2,675.00 39.60 24.06 2,520.69 2,360.69 553.73 234.18 2,500,048.16 214,422.00 0.19 599.01 NSG-CT_D/P(1) 2,700.00 39.52 23.88 2,539.97 2,379.97 568.28 240.65 2,500,062.55 214,428.82 0.56 614.85 NSG-CT_D/P(1) 2,725.00 39.30 23.96 2,559.28 2,399.28 582.79 247.08 2,500,076.89 214,435.61 0.90 630.64 NSG-CT_D/P(1) 2,750.00 39.26 24.03 2,578.64 2,418.64 597.25 253.52 2,500,091.19 214,442.40 0.24 646.38 NSG-CT_D/P(1) 2,775.00 39.29 24.01 2,597.99 2,437.99 611.70 259.96 2,500,105.49 214,449.19 0.13 662.12 NSG-CT_D/P(1) 2,800.00 39.26 24.06 2,617.34 2,457.34 626.16 266.41 2,500,119.78 214,455.99 0.17 677.86 NSG-CT_D/P(1) 2,825.00 39.24 24.02 2,636.70 2,476.70 640.60 272.85 2,500,134.06 214,462.78 0.13 693.59 NSG-CT_D/P(1) 2,850.00 39.09 24.01 2,656.08 2,496.08 655.02 279.28 2,500,148.32 214,469.56 0.60 709.29 NSG-CT_D/P(1) 2,875.00 38.84 23.99 2,675.52 2,515.52 669.39 285.67 2,500,162.52 214,476.30 1.00 724.92 NSG-CT_D/P(1) 2,900.00 38.99 24.03 2,694.97 2,534.97 683.73 292.06 2,500,176.71 214,483.04 0.61 740.54 NSG-CT_D/P(1) 2,925.00 38.89 24.03 2,714.42 2,554.42 698.08 298.46 2,500,190.90 214,489.79 0.40 756.17 NSG-CT_D/P(1) 2,950.00 38.69 23.88 2,733.91 2,573.91 712.39 304.82 2,500,205.05 214,496.49 0.88 771.75 NSG-CT_D/P(1) 2,975.00 38.76 23.91 2,753.41 2,593.41 726.69 311.15 2,500,219.19 214,503.17 0.29 787.30 NSG-CT_D/P(1) 3,000.00 38.48 24.03 2,772.94 2,612.94 740.95. 317.49 2,500,233.29 214,509.86 1.16 802.82 NSG-CT_D/P(1) 3,025.00 38.59 24.04 2,792.50 2,632.50 755.18 323.84 2,500,247.36 214,516.55 0.44 818.31 NSG-CT_D/P(1) 3,050.00 38.52 23.99 2,812.05 2,652.05 769.41 330.18 2,500,261.43 214,523.24 0.31 833.81 NSG-CT_D/P(1) 3,075.00 38.57 23.87 2,831.60 2,671.60 783.65 336.50 2,500,275.51 214,529.90 0.36 849.30 NSG-CT_D/P(1) 3,100.00 38.42 23.91 2,851.17 2,691.17 797.88 342.80 2,500,289.58 214,536.55 0.61 864.78 NSG-CT_D/P(1) 3,125.00 38.36 24.09 2,870.76 2,710.76 812.06 349.12 2,500,303.60 214,543.21 0.51 880.22 NSG-CT_D/P(1) 3,150.00 38.45 24.11 2,890.35 2,730.35 826.23 355.46 2,500,317.62 214,549.89 0.36 895.67 NSG-CT_D/P(1) 3,175.00 38.45 24.08 2,909.93 2,749.93 840.43 361.80 2,500,331.65 214,556.59 0.07 911.13 NSG-CT_D/P(1) 3,200.00 38.31 23.86 2,929.53 2,769.53 854.61 368.11 2,500,345.68 214,563.24 0.78 926.56 NSG-CT_D/P(1) 3,225.00 38.20 23.97 2,949.16 2,789.16 868.76 374.39 2,500,359.67 214,569.65 0.52 941.96 NSG-CT_D/P(1) 3,250.00 38.06 23.85 2,968.83 2,808.83 882.87 380.64 2,500,373.62 214,576.45 0.63 957.32 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 5 COMPASS 5000.1 Build 81 i • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,275.00 38.07 23.87 2,988.51 2,828.51 896.97 386.88 2,500,387.56 214,583.03 0.06 972.65 NSG-CT_D/P(1) 3,300.00 38.10 23.87 3,008.19 2,848.19 911.07 393.12 2,500,401.51 214,589.61 0.12 987.99 NSG-CT_D/P(1) 3,325.00 38.02 23.79 3,027.87 2,867.87 925.17 399.35 2,500,415.45 214,596.18 0.38 1,003.32 NSG-CT_D/P(1) 3,350.00 37.86. 23.92 3,047.59 2,887.59 939.22 405.56 2,500,429.35 214,602.74 0.72 1,018.61 NSG-CT_D/P(1) 3,375.00 37.60 24.11 3,067.36 2,907.36 953.20 411.79 2,500,443.17 214,609.31 1.14 1,033.83 NSG-CT_D/P(1) 3,400.00 37.55 24.28 3,087.17 2,927.17 967.10 418.04 2,500,456.92 214,615.89 0.46 1,048.99 NSG-CT_D/P(1) 3,425.00 37.52 24.30 3,107.00 2,947.00 980.99 424.30 2,500,470.65 214,622.50 0.13 1,064.13 NSG-CT_D/P(1) 3,450.00 37.30 24.25 3,126.86 2,966.86 994.83 430.55 2,500,484.33 214,629.08 0.89 1,079.22 NSG-CT_D/P(1) 3,475.00 37.28 24.40 3,146.75 2,986.75 1,008.63 436.79 2,500,497.98 214,635.65 0.37 1,094.28 NSG-CT_D/P(1) 3,500.00 37.36 24.41 3,166.63 3,006.63 1,022.44 443.05 2,500,511.62 214,642.25 0.32 1,109.34 NSG-CT_D/P(1) 3,525.00 37.38 24.46 3,186.50 3,026.50 1,036.25 449.33 2,500,525.28 214,648.86 0.15 1,124.42 NSG-CT_D/P(1) 3,550.00 37.27 24.50 3,206.38 3,046.38 1,050.05 455.61 2,500,538.92 214,655.48 0.45 1,139.48 NSG-CT_D/P(1) 3,575.00 37.32 24.31 3,226.26 3,066.26 1,063.84 461.87 2,500,552.56 214,662.07 0.50 1,154.54 NSG-CT_D/P(1) 3,600.00 37.24 24.39 3,246.16 3,086.16 1,077.64 468.11 2,500,566.20 214,668.65 0.37 1,169.59 NSG-CT_D/P(1) 3,625.00 37.29 24.45 3,266.05 3,106.05 1,091.42 474.37 2,500,579.82 214,675.24 0.25 1,184.63 NSG-CT_D/P(1) 3,650.00 37.32 24.32 3,285.94 3,125.94 1,105.22 480.62 2,500,593.46 214,681.83 0.34 1,199.69 NSG-CT_D/P(1) 3,675.00 37.26 24.34 3,305.83 3,145.83 1,119.02 486.86 2,500,607.11 214,688.41 0.24 1,214.74 NSG-CT_D/P(1) 3,700.00 37.03 24.47 3,325.76 3,165.76 1,132.77 493.10 2,500,620.70 214,694.98 0.97 1,229.74 NSG-CT_D/P(1) 3,725.00 36.95 24.49 3,345.72 3,185.72 1,146.46 499.34 2,500,634.23 214,701.55 0.32 1,244.69 NSG-CT_D/P(1) 3,750.00 37.17 24.67 3,365.67 3,205.67 1,160.16 505.60 2,500,647.78 214,708.14 0.98 1,259.66 NSG-CT_D/P(1) 3,775.00 37.29 24.58 3,385.58 3,225.58 1,173.91 511.91 2,500,661.37 214,714.78 0.53 1,274.68 NSGCT_D/P(1) 3,800.00 37.17 24.55 3,405.48 3,245.48 1,187.66 518.19 2,500,674.97 214,721.40 0.49 1,289.71 NSG-CT_D/P(1) 3,825.00 37.03 24.56 3,425.42 3,265.42 1,201.38 524.46 2,500,688.53 214,728.00 0.56 1,304.69 NSG-CT_D/P(1) 3,850.00 36.90 24.59 3,445.40 3,285.40 1,215.05 530.71 2,500,702.04 214,734.59 0.52 1,319.63 NSG-CT_D/P(1) 3,875.00 36.74 24.59 3,465.41 3,305.41 1,228.67 536.95 2,500,715.51 214,741.15 0.64 1,334.51 NSG-CT_D/P(1) 3,900.00 36.60 24.58 3,485.46 3,325.46 1,242.25 543.16 2,500,728.93 214,747.69 0.56 1,349.34 NSG-CT_D/P(1) 3,925.00 36.68 24.52 3,505.52 3,345.52 1,255.82 549.36 2,500,742.34 214,754.22 0.35 1,364.17 NSG-CT_D/P(1) 3,950.00 36.47 24.45 3,525.60 3,365.60 1,269.38 555.53 2,500,755.75 214,760.73 0.86 1,378.97 NSG-CT_D/P(1) 3,975.00 36.49 24.27 3,545.70 3,385.70 1,282.92 561.66 2,500,769.13 214,767.19 0.44 1,393.74 NSG-CT_D/P(1) 4,000.00 36.63 24.12 3,565.78 3,405.78 1,296.50 567.77 2,500,782.56 214,773.62 0.66 1,408.55 NSG-CT_D/P(1) 4,025.00 36.67 23.70 3,585.84 3,425.84 1,310.14 573.82 2,500,796.05 214,780.00 1.02 1,423.39 NSG-CT_D/P(1). 4,050.00 36.75 23.28 3,605.88 3,445.88 1,323.85 579.77 2,500,809.61 214,786.29 1.05 1,438.27 NSG-CT_D/P(1) 4,075.00 36.94 23.05 3,625.89 3,465.89 1,337.63 585.67 2,500,823.24 214,792.52 0.94 1,453.20 NSG-CT_D/P(1) 4,100.00 37.14 22.79 3,645.84 3,485.84 1,351.50 591.54 2,500,836.97 214,798.72 1.02 1,468.20 NSG-CT_D/P(1) 4,125.00 37.43 22.62 3,665.74 3,505.74 1,365.47 597.38 2,500,850.79 214,804.91 1.23 1,483.29 NSG-CT_D/P(1) 4,150.00 37.72 22.38 3,685.55 3,525.55 1,379.56 603.22 2,500,864.73 214,811.08 1.30 1,498.49 NSG-CT_D/P(1) 4,175.00 37.57 21.85 3,705.34 3,545.34 1,393.70 608.96 2,500,878.73 214,817.18 1.43 1,513.72 NSG-CT_D/P(1) 4,200.00 37.71 21.71 3,725.14 3,565.14 1,407.88 614.63 2,500,892.76 214,823.19 0.66 1,528.96 NSG-CT_D/P(1) 4,225.00 37.92 21.67 3,744.89 3,584.89 1,422.12 620.29 2,500,906.86 214,829.20 0.85 1,544.25 NSG-CT_D/P(1) 4,250.00 38.14 21.57 3,764.58 3,604.58 1,436.44 625.97 2,500,921.04 214,835.22 0.91 1,559.62 NSG-CT_D/P(1) 5/17/2017 12.01:45PM Page 6 COMPASS 5000.1 Build 81 0 • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,275.00 38.26 21.55 3,784.23 3,624.23 1,450.82 631.65 2,500,935.27 214,841.25 0.48 1,575.06 NSG-CT_D/P(1) 4,300.00 38.44 21.57 3,803.84 3,643.84 1,465.25 637.35 2,500,949.56 214,847.30 0.72 1590.54 NSG-CT_D/P(1) 4,325.00 38.61 21.56 3523.39 3,663.39 1,479.73 643.08 2,500,963.89 214,853.38 0.68 1,606.08 NSG-CT_D/P(1) 4,350.00 39.04 21.57 3,842.87 3,682.87 1,494.30 648.84 2,500,978.32 214,859.49 1.72 1,621.72 NSG-CT_D/P(1) 4,375.00 39.32 21.49 3,862.25 3,702.25 1,509.00 654.63 2,500,992.87 214,865.65 1.14 1,637.49 NSG-CT_D/P(1) 4,400.00 39.51 21.51 3,881.56 3,721.56 1,523.76 660.45 2,501,007.49 214,871.82 0.76 1,653.33 NSG-CT_D/P(1) 4,425.00 39.58 21.22 3,900.84 3,740.84 1,538.59 666.25 2,501,022.17 214,877.98 0.79 1,669.22 NSG-CT_D/P(1) 4,450.00 39.74 21.10 3,920.09 3,760.09 1,553.47 672.01 2,501,036.90 214,884.10 0.71 1,685.15 NSG-CT_D/P(1) 4,475.00 39.96 20.93 3,939.28 3,779.28 1,568.42 677.75 2,501,051.71 214,890.21 0.98 1,701.15 NSG-CT_D/P(1) 4,500.00 40.04 20.65 3,958.43 3,798.43 1,583.44 683.46 2,501,066.59 214,896.28 0.79 1,717.20 NSG-CT_D/P(1) 4,525.00 40.15 20.59 3,977.56 3,817.56 1,598.51 689.13 2,501,081.52 214,902.32 0.47 1,733.29 NSG-CT_D/P(1) 4,550.00 40.06 20.52 3,996.68 3,836.68 1,613.59 694.78 2,501,096.46 214,908.34 0.40 1,749.38 NSG-CT_D/P(1) 4,575.00 39.93 20.60 4,015.83 3,855.83 1,628.64 700.43 2,501,111.36 214,914.35 0.56 1,765.43 NSG-CT_D/P(1) 4,600.00 39.90 20.48 4,035.01 3,875.01 1,643.66 706.06 2,501,126.24 214,920.34 0.33 1,781.45 NSG-CT_D/P(1) 4,625.00 40.00 20.47 4,054.17 3,894.17 1,658.70 711.67 2,501,141.13 214,926.32 0.40 1,797.49 NSG-CT_D/P(1) 4,650.00 39.98 20.52 4,073.33 3,913.33 1,673.75 717.30 2,501,156.04 214,932.31 0.15 1,813.54 NSG-CT_D/P(1) 4,675.00 39.87 20.55 4,092.50 3,932.50 1,688.77 722.93 2,501,170.92 214,938.31 0.45 1,829.57 NSG-CT_D/P(1) 4,700.00 40.09 20.58 4,111.65 3,951.65 1,703.81 728.57 2,501,185.82 214,944.31 0.88 1,845.62 NSG-CT_D/P(1) 4,725.00 40.43 20.62 4,130.73 3,970.73 1,718.93 734.25 2,501,200.80 214,950.37 1.36 1,861.76 NSG-CT_D/P(1) 4,750.00 40.56 20.62 4,149.74 3,989.74 1,734.13 739.97 2,501,215.85 214,956.45 0.52 1,877.98 NSG-CT_D/P(1) 4,775.00 40.21 20.45 4,168.79 4,008.79 1,749.30 745.65 2,501,230.88 214,962.50 1.47 1,894.16 NSG-CT_D/P(1) 4,800.00 40.25 20.48 4,187.87 4,027.87 1,764.42 751.30 2,501,245.86 214,968.52 0.18 1,910.29 NSG-CT_D/P(1) 4,825.00 40.14 20.51 4,206.97 4,046.97 1,779.54 756.95 2,501,260.83 214,974.53 0.45 1,926.41 NSG-CT_D/P(1) 4,850.00 40.08 20.50 4,226.09 4,066.09 1,794.62 762.59 2,501,275.78 214,980.54 0.24 1,942.50 NSG-CT_D/P(1) 4,875.00 40.12 20.43 4,245.21 4,085.21 1,809.71 768.22 2,501,290.72 214,986.54 0.24 1,958.59 NSG-CT_D/P(1) 4,900.00 40.00 20.52 4,264.35 4,104.35 1,824.78 773.85 2,501,305.65 214,992.53 0.53 1,974.67 NSG-CT_D/P(1) 4,925.00 39.98 20.51 4,283.50 4,123.50 1,839.83 779.48 2,501,320.56 214,998.53 0.08 1,990.72 NSG-CT_D/P(1) 4,950.00 40.11 20.46 4,302.64 4,142.64 1,854.90 785.11 2,501,335.48 215,004.53 0.54 2,006.79 NSG-CT_D/P(1) 4,975.00 40.00 20.41 4,321.77 4,161,77 1,869.97 790.73 2,501,350.42 215,010.51 0.46 2,022.86 NSG-CT_D/P(1) 5,000.00 40.21 20.40 4,340.90 4,180.90 1,885.07 796.34 2,501,365.37 215,016.49 0.84 2,038.95 NSG-CT_D/P(1) 5,025.00 40.36 20.42 4,359.97 4,199.97 1,900.22 801.98 2,501,380.38 215,022.50 0.60 2,055.10 NSG-CT_D/P(1) 5,050.00 40.18 20.51 4,379.04 4,219.04 1,915.36 807.63 2,501,395.37 215,028.52 0.76 2,071.25 NSG-CT_D/P(1) 5,075.00 40.21 20.54 4,398.14 4,238.14 1,930.47 813.29 2,501,410.34 215,034.54 0.14 2,087.37 NSG-CT_D/P(1) 5,100.00 40.28 20.59 4,417.22 4,257.22 1,945.59 818.96 2,501,425.32 215,040.58 0.31 2,103.50 NSG-CT_D/P(1) 5,125.00 40.14 20.56 4,436.31 4,276.31 1,960.70 824.63 2,501,440.29 215,046.62 0.57 2,119.62 NSG-CT_D/P(1) 5,150.00 39.46 20.66 4,455.52 4,295.52 1,975.68 830.27 2,501,455.12 215,052.62 2.73 2,135.61 NSG-CT_D/P(1) 5,1.75.00 39.25 20.74 4,474.85 4,314.85 1,990.51 835.87 2,501,469.81 215,058.58 0.86 2,151.45 NSG-CT_D/P(1) 5,200.00 39.67 20.79 4,494.15 4,334.15 2,005.36 841.50 2,501,484.53 215,064.58 1.68 2,167.32 NSG-CT_D/P(1) 5,225.00 39.86 20.78 4,513.37 4553.37 2,020.31 847.18 2,501,499.33 215,070.62 0.76 2,183.29 NSG-CT_D/P(1) 5,250.00 39.89 20.83 4,532.56 4,372.56 2,035.30 852.87 2,501,514.17 215,076.67 0.18 2,199.30 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 7 COMPASS 5000.1 Build 81 III • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-5 +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,275.00 39.31 20.93 4,551.82 4,391.82 2,050.19 858.55 2,501,528.92 215,082.71 2.33 2,215.21 NSG-CT_D/P(1) 5,300.00 39.13 20.93 4,571.19 4,411.19 2,064.95 864.20 2,501,543.54 215,088.72 0.72 2,231.00 NSG-CT_D/P(1) 5,325.00 39.12 21.02 4,590.58 4,430.58 2,079.68 869.85 2,501,558.13 215,094.73 0.23 2,246.76 NSG-CT_D/P(1) 5,350.00 38.99 20.99 4,609.99 4,449.99 2,094.39 875.49 2,501,572.69 215,100.73 0.53 2,262.49 NSG-CT_D/P(1) 5,375.00 38.96 20.92 4,629.43 4,469.43 2,109.07 881.12 2,501,587.23 215,106.71 0.21 2,278.19 NSG-CT_D/P(1) 5,400.00 39.21 20.89 4,648.83 4,488.83 2,123.79 886.74 2,501,601.81 215,112.69 1.00 2,293.93 NSG-CT_D/P(1) 5,425.00 39.11 20.78 4,668.22 4,508.22 2,138.55 892.36 2,501,616.43 215,118.67 0.49 2,309.70 NSG-CT_D/P(1) 5,450.00 38.79 20.81 4,687.66 4,527.66 2,153.24 897.94 2,501,630.98 215,124.60 1.28 2,325.40 NSG-CT_D/P(1) 5,475.00 38.26 20.89 4,707.22 4,547.22 2,167.79 903.48 2,501,645.39 215,130.50 2.13 2,340.95 NSG-CT_D/P(1) 5,500.00 38.19 20.89 4,726.86 4,566.86 2,182.24 908.99 2,501,659.70 215,136.37 0.28 2,356.40 NSG-CT_D/P(1) 5,525.00 38.30 20.92 4,746.49 4,586.49 2,196.70 914.52 2,501,674.02 215,142.24 0.45 2,371.85 NSG-CT_D/P(1) 5,550.00 38.53 20.93 4,766.08 4,606.08 2,211.21 920.07 2,501,688.39 215,148.14 0.92 2,387.37 NSG-CT_D/P(1) 5,575.00 38.64 20.83 4,785.62 4,625.62 2,225.78 925.62 2,501,702.82 215,154.05 0.51 2,402.94 NSG-CT_D/P(1) 5,600.00 38.54 20.76 4,805.16 4,645.16 2,240.36 931.16 2,501,717.26 215,159.94 0.44 2,418.52 NSG-CT_D/P(1) 5,625.00 38.57 20.88 4,824.72 4,664.72 2,254.92 936.70 2,501,731.68 215,165.83 0.32 2,434.08 NSG-CT_D/P(1) 5,650.00 38.49 20.72 4,844.27 4,684.27 2,269.48 942.23 2,501,746.10 215,171.72 0.51 2,449.63 NSG-CT_D/P(1) 5,675.00 38.41 20.75 4,863.85 4,703.85 2,284.02 947.73 2,501,760.50 215,177.58 0.33 2,465.16 NSG-CT_D/P(1) 5,700.00 38.31 20.63 4,883.45 4,723.45 2,298.53 953.21 2,501,774.88 215,183.41 0.50 2,480.66 NSG-CT_D/P(1) 5,725.00 38.28 20.55 4,903.07 4,743.07 2,313.03 958.66 2,501,789.24 215,189.21 0.23 2,496.14 NSG-CT_D/P(1) 5,750.00 38.33 20.45 4,922.69 4,762.69 2,327.55 964.09 2,501,803.62 215,194.99 0.32 2,511.62 NSG-CT_D/P(1) 5,775.00 38.57 20.41 4,942.27 4,782.27 2,342.12 969.52 2,501,818.05 215,200.77 0.97 2,527.15 NSG-CT_D/P(1) 5,800.00 38.82 20.34 4,961.78 4,801.78 2,356.77 974.96 2,501,832.56 215,206.57 1.02 2,542.77 NSG-CT_D/P(1) 5,825.00 38.82 20.33 4,981.26 4,821.26 2,371.46 980.40 2,501,847.12 215,212.37 0.03 2,558.43 NSG-CT_D/P(1) 5,850.00 38.40 20.14 5,000.80 4,840.80 2,386.10 985.80 2,501,861.62 215,218.12 1.75 2,574.02 NSG-CT_D/P(1) 5,875.00 38.53 20.11 5,020.37 4,860.37 2,400.70 991.15 2,501,876.09 215,223.83 0.53 2,589.56 NSG-CT_D/P(1) 5,900.00 38.83 20.10 5,039.89 4,879.89 2,415.37 996.52 2,501,890.63 215,229.56 1.20 2,605.17 NSG-CT_D/P(1) 5,925.00 39.12 20.11 5,059.32 4,899.32 2,430.14 1,001.93 2,501,905.25 215,235.32 1.16 2,620.88 NSG-CT_D/P(1) 5,950.00 38.91 19.98 5,078.75 4,918.75 2,444.92 1,007.32 2,501,919.90 215,241.08 0.90 2,636.61 NSG-CT_D/P(1) 5,975.00 38.64 20.04 5,098.24 4,938.24 2,459.64 1,012.68 2,501,934.48 215,246.79 1.09 2,652.26 NSG-CT_D/P(1) 6,000.00 38.71 20.12 5,117.76 4,957.76 2,474.31 1,018.04 2,501,949.02 215,252.51 0.34 2,667.87 NSG-CT_D/P(1) 6,025.00 39.19 20.08 5,137.20 4,977.20 2,489.07 1,023.45 2,501,963.64 215,258.27 1.92 2,683.58 NSG-CT_D/P(1) 6,050.00 39.37 20.02 5,156.55 4,996.55 2,503.94 1,028.87 2,501,978.37 215,264.06 0.74 2,699.39 NSG-CT_D/P(1) 6,075.00 39.49 20.14 5,175.86 5,015.86 2,518.85 1,034.32 2,501,993.15 215,269.87 0.57 2,715.26 NSG-CT_D/P(1) 6,100.00 39.52 20.25 5,195.15 5,035.15 2,533.77 1,039.81 2,502,007.93 215,275.73 0.30 2,731.16 NSG-CT_D/P(1) 6,125.00 39.42 20.18 5,214.45 5,054.45 2,548.69 1,045.31 2,502,022.71 215,281.58 0.44 2,747.04 NSG-CT_D/P(1) 6,150.00 39.51 20.19 5,233.75 5,073.75 2,563.60 1,050.79 2,502,037.48 215,287.43 0.36 2,762.91 NSG-CT_D/P(1) 6,175.00 39.73 20.17 5,253.01 5,093.01 2,578.57 1,056.29 2,502,052.31 215,293.29 0.88 2,778.85 NSG-CT_D/P(1) 6,200.00 39.96 20.26 5,272.20 5,112.20 2,593.60 1,061.82 2,502,067.20 215,299.19 0.95 2,794.85 NSG-CT_D/P(1) 6,225.00 39.59 20.22 5,291.41 5,131.41 2,608.60 1,067.36 2,502,082.07 215,305.09 1.48 2,810.83 NSG-CT_D/P(1) 6,250.00 39.85 20.32 5,310.64 5,150.64 2,623.59 1,072.89 2,502,096.91 215,310.99 1.07 2,826.80 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 8 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.O0usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1O0') (ft) Survey Tool Name 6,275.00 39.90 20.24 5,329.83 5,169.83 2,638.62 1,078.45 2,502,111.81 215,316.91 0.29 2,842.81 NSG-CT_D/P(1) 6,300.00 40.12 20.28 5,348.98 5,188.98 2,653.70 1,084.02 2,502,126.74 215,322.84 0.89 2,858.87 NSG-CT_D/P(1) 6,325.00 40.50 20.32 5,368.04 5,208.04 2,668.87 1,089.63 2,502,141.77 215,328.82 1.52 2,875.03 NSG-CT_D/P(1) 6,350.00 40.43 20.63 5,387.06 5,227.06 2,684.07 1,095.30 2,502,156.83 215,334.87 0.85 2,891.24 NSG-CT_D/P(1) 6,375.00 40.29 20.77 5,406.11 5,246.11 2,699.21 1,101.03 2,502,171.83 215,340.96 0.67 2,907.42 NSG-CT_D/P(1) 6,400.00 40.35 20.96 5,425.17 5,265.17 2,714.33 1,106.79 2,502,186.80 215,347.09 0.55 2,923.57 NSG-CT_D/P(1) 6,425.00 40.34 21.09 5,444.23 5,284.23 2,729.44 1,112.59 2,502,201.76 215,353.26 0.34 2,939.73 NSG-CT_D/P(1) 6,450.00 39.99 21.49 5,463.33 5,303.33 2,744.46 1,118.45 2,502,216.64 215,359.48 1.74 2,955.83 NSG-CT_D/P(1) 6,475.00 39.75 21.91 5,482.52 5,322.52 2,759.35 1,124.37 2,502,231.38 215,365.77 1.44 2,971.83 NSG-CT_D/P(1) 6,500.00 39.83 22.33 5,501.73 5,341.73 2,774.17 1,130.40 2,502,246.05 215,372.15 1.12 2,987.76 NSG-CT_D/P(1) 6,525.00 39.98 22.71 5,520.91 5,360.91 2,788.99 1,136.54 2,502,260.71 215,378.66 1.14 3,003.77 NSG-CT_D/P(1) 6,550.00 39.52 22.89 5,540.13 5,380.13 2,803.72 1,142.74 2,502,275.29 215,385.21 1.90 3,019.70 NSG-CT_D/P(1) 6,575.00 39.53 23.01 5,559.41 5,399.41 2,818.38 1,148.94 2,502,289.78 215,391.77 0.31 3,035.55 NSG-CT_D/P(1) 6,600.00 39.72 23.09 5,578.67 5,418.67 2,833.05 1,155.18 2,502,304.30 215,398.37 0.79 3,051.44 NSG-CT_D/P(1) 6,625.00 40.02 23.11 5,597.85 5,437.85 2,847.79 1,161.47 2,502,318.88 215,405.01 1.20 3,067.40 NSG-CT_D/P(1) 6,650.00 40.09 23.28 5,616.99 5,456.99 2,862.57 1,167.81 2,502,333.51 215,411.71 0.52 3,083.42 NSG-CT_13/P(1) 6,675.00 39.87 23.46 5,636.15 5,476.15 2,877.32 1,174.18 2,502,348.09 215,418.44 0.99 3,099.42 NSG-CT_D/P(1) 6,700.00 39.82 23.75 5,655.34 5,495.34 2,892.00 1,180.60 2,502,362.61 215,425.21 0.77 3,115.36 NSG-CT_D/P(1) 6,725.00 40.20 24.11 5,674.49 5,514.49 2,906.69 1,187.12 2,502,377.14 215,432.09 1.78 3,131.34 NSG-CT_D/P(1) 6,750.00 40.38 24.50 5,693.56 5,533.56 2,921.42 1,193.77 2,502,391.70 215,439.10 1.24 3,147.41 NSG-CT_D/P(1) 6,775.00 40.26 25.00 5,712.62 5,552.62 2,936.11 1,200.54 2,502,406.22 215,446.23 1.38 3,163.48 NSG-CT_D/P(1) 6,800.00 40.20 25.25 5,731.71 5,571.71 2,950.73 1,207.40 2,502,420.67 215,453.44 0.69 3,179.50 NSG-CT_D/P(1) 6,825.00 40.25 25.43 5,750.79 5,590.79 2,965.32 1,214.31 2,502,435.09 215,460.70 0.51 3,195.51 NSG-CT_D/P(1) 6,850.00 40.21 25.44 5,769.88 5,609.88 2,979.90 1,221.24 2,502,449.50 215,467.99 0.16 3,211.53 NSG-CT_D/P(1) 6,875.00 40.04 25.45 5,789.00 5,629.00 2,994.45 1,228.17 2,502,463.87 215,475.27 0.68 3,227.50 NSG-CT_D/P(1) 6,900.00 40.19 25.50 5,808.12 5,648.12 3,008.99 1,235.09 2,502,478.24 215,482.55 0.61 3,243.47 NSG-CT_D/P(1) 6,925.00 40.22 25.48 5,827.21 5,667.21 3,023.56 1,242.04 2,502,492.63 215,489.85 0.13 3,259.47 NSG-CT_D/P(1) 6,950.00 40.16 25.34 5,846.31 5,686.31 3,038.13 1,248.96 2,502,507.03 215,497.12 0.43 3,275.47 NSG-CT_D/P(1) 6,975.00 40.35 25.28 5,865.39 5,705.39 3,052.74 1,255.87 2,502,521.46 215,504.39 0.78 3,291.50 NSG-CT_D/P(1) 7,000.00 40.58 25.13 5,884.41 5,724.41 3,067.42 1,262.78 2,502,535.97 215,511.65 1.00 3,307.59 NSG-CT_D/P(1) 7,025.00 40.59 24.61 5,903.39 5,743.39 3,082.17 1,269.62 2,502,550.55 215,518.85 1.35 3,323.74 NSG-CT_D/P(1) 7,050.00 40.74 24.34 5,922.36 5,762.36 3,097.00 1,276.37 2,502,565.21 215,525.96 0.92 3,339.93 NSG-CT_D/P(1) 7,075.00 40.73 23.60 5,941.30 5,781.30 3,111.91 1,283.00 2,502,579.95 215,532.95 1.93 3,356.16 NSG-CT_D/P(1) 7,100.00 40.93 22.85 5,960.22 5,800.22 3,126.93 1,289.44 2,502,594.81 215,539.76 2.12 3,372.43 NSG-CT_D/P(1) 7,125.00 41.34 22.33 5,979.05 5,819.05 3,142.11 1,295.76 2,502,609.83 215,546.45 2.14 3,388.83 NSG-CT_D/P(1) 7,150.00 41.02 21.77 5,997.86 5,837.86 3,157.37 1,301.94 2,502,624.94 215,553.00 1.95 3,405.25 NSG-CT_D/P(1) 7,175.00 41.18 21.42 6,016.70 5,856.70 3,172.65 1,307.99 2,502,640.06 215,559.42 1.12 3,421.65 NSG-CT_D/P(1) 7,200.00 40.89 20.77 6,035.56 5,875.56 3,187.96 1,313.90 2,502,655.23 215,565.70 2.06 3,438.04 NSG-CT_D/P(1) 7,225.00 40.56 20.20 6,054.50 5,894.50 3,203.24 1,319.60 2,502,670.36 215,571.78 1.99 3,454.33 NSG-CT_D/P(1) 7,250.00 40.69 19.91 6,073.48 5,913.48 3,218.53 1,325.19 2,502,685.51 215,577.73 0.92 3,470.60 NSG-CT_D/P(1) 5/17/2017 12.:01:45PM Page 9 COMPASS 5000.1 Build 81 • • Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical ' MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,275.00 40.81 19.85 6,092.42 5,932.42 3,233.88 1,330.74 2,502,700.72 215,583.65 0.50 3,486.91 NSG-CT_D/P(1) 7,300.00 40.74 19.97 6,111.35 5,951.35 3,249.23 1,336.30 2,502,715.93 215,589.59 0.42 3,503.23 NSG-CT_D/P(1) 7,325.00 40.57 19.93 6,130.32 5,970.32 3,264.54 1,341.85 2,502,731.10 215,595.51 0.69 3,519.51 NSG-CT_D/P(1) 7,350.00 40.54 19.92 6,149.31 5,989.31 3,279.82 1,347.39 2,502,746.24 215,601.43 0.12 3,535.75 NSG-CT_D/P(1) 7,375.00 40.69 19.99 6,168.29 6,008.29 3,295.12 1,352.95 2,502,761.40 215,607.35 0.63 3,552.02 NSG-CT_D/P(1) 7,400.00 40.94 20.05 6,187.21 6,027.21 3,310.47 1,358.54 2,502,776.61 215,613.32 1.01 3,568.35 NSG-CT_D/P(1) 7,425.00 41.34 20.16 6,206.04 6,046.04 3,325.91 1,364.20 2,502,791.91 215,619.35 1.63 3,584.79 NSG-CT_D/P(1) 7,450.00 41.24 20.15 6,224.82 6,064.82 3,341.40 1,369.88 2,502,807.25 215,625.41 0.40 3,601.27 NSG-CT_D/P(1) 7,475.00 41.27 20.07 6,243.62 6,083.62 3,356.88 1,375.55 2,502,822.59 215,631.45 0.24 3,617.75 NSG-CT_D/P(1) 7,500.00 41.29 20.14 6,262.40 6,102.40 3,372.37 1,381.22 2,502,837.94 215,637.50 0.20 3,634.23 NSG-CT_D/P(1) 7,525.00 41.36 20.16 6,281.18 6,121.18 3,387.87 1,386.91 2,502,853.29 215,643.56 0.28 3,650.72 NSG-CT_D/P(1) 7,550.00 41.51 20.20 6,299.92 6,139.92 3,403.39 1,392.61 2,502,868.68 215,649.65 0.61 3,667.26 NSG-CT_D/P(1) 7,575.00 41.39 20.30 6,318.66 6,158.66 3,418.92 1,398.34 2,502,884.06 215,655.75 0.55 3,683.79 NSG-CT_D/P(1) 7,600.00 41.31 20.26 6,337.43 6,177.43 3,434.41 1,404.07 2,502,899.40 215,661.86 0.34 3,700.30 NSG-CT_D/P(1) 7,625.00 41.20 20.15 6,356.22 6,196.22 3,449.88 1,409.76 2,502,914.73 215,667.93 0.53 3,716.77 NSG-CT_D/P(1) 7,650.00 41.04 20.15 6,375.05 6,215.05 3,465.32 1,415.43 2,502,930.02 215,673.96 0.64 3,733.20 NSG-CT_D/P(1) 7,675.00 41.38 20.20 6,393.86 6,233.86 3,480.78 1,421.11 2,502,945.34 215,680.02 1.37 3,749.66 NSG-CT_D/P(1) 7,700.00 41.43 20.13 6,412.61 6,252.61 3,496.30 1,426.81 2,502,960.72 215,686.10 0.27 3,766.18 NSG-CT_D/P(1) 7,725.00 41.34 20.05 6,431.37 6,271.37 3,511.82 1,432.48 2,502,976.10 215,692.15 0.42 3,782.70 NSG-CT_D/P(1) 7,750.00 41.20 20.14 6,450.16 6,290.16 3,527.31 1,438.15 2,502,991.44 215,698.20 0.61 3,799.18 NSG-CT_D/P(1) 7,775.00 41.32 20.39 6,468.95 6,308.95 3,542.77 1,443.86 2,503,006.76 215,704.28 0.82 3,815.65 NSG-CT_D/P(1) 7,800.00 41.33 20.64 6,487.73 6,327.73 3,558.24 1,449.65 2,503,022.08 215,710.44 0.66 3,832.15 NSG-CT_D/P(1) 7,825.00 41.32 20.78 6,506.50 6,346.50 3,573.68 1,455.48 2,503,037.37 215,716.66 0.37 3,848.64 NSG-CT_D/P(1) 7,850.00 41.37 20.83 6,525.27 6,365.27 3,589.11 1,461.35 2,503,052.66 215,722.90 0.24 3,865.13 NSG-CT_D/P(1) 7,875.00 41.26 20.84 6,544.05 6,384.05 3,604.54 1,467.22 2,503,067.94 215,729.14 0.44 3,881.62 NSG-CT_D/P(1) 7,900.00 41.16 20.93 6,562.86 6,402.86 3,619.93 1,473.09 2,503,083.18 215,735.39 0.47 3,898.07 NSG-CT_D/P(1) 7,925.00 41.50 20.78 6,581.63 6,421.63 3,635.36 1,478.97 2,503,098.46 215,741.64 1.42 3,914.56 NSG-CT_D/P(1) 7,950.00 41.63 20.77 6,600.33 6,440.33 3,650.86 1,484.86 2,503,113.82 215,747.90 0.52 3,931.12 NSG-CT_D/P(1) 7,975.00 41.40 21.10 6,619.05 6,459.05 3,666.34 1,490.78 2,503,129.14 215,754.20 1.27 3,947.67 NSG-CT_D/P(1) 8,000.00 41.54 21.03 6,637.79 6,477.79 3,681.79 1,496.73 2,503,144.44 215,760.53 0.59 3,964.20 NSG-CT_D/P(1) 8,025.00 41.35 20.95 6,656.53 6,496,53 3,697.24 1,502.65 2,503,159.74 215,766.83 0.79 3,980.73 NSG-CT_D/P(1) 8,050.00 41.62 21.00 6,675.25 6,515.25 3,712.70 1,508.58 2,503,175.06 215,773.13 1.09 3,997.27 NSG-CT_D/P(1) 8,075.00 41.94 21.07 6,693.90 6,533.90 3,728.25 1,514.56 2,503,190.45 215,779.49 1.29 4,013.90 NSG-CT_D/P(1) 8,100.00 42.27 21.15 6,712.44 6,552.44 3,743.89 1,520.60 2,503,205.94 215,785.91 1.34 4,030.64 NSG-CT_D/P(1) 8,125.00 41.91 20.76 6,731.00 6,571.00 3,759.54 1,526.59 2,503,221.44 215,792.28 1.78 4,047.37 NSG-CT_D/P(1) 8,150.00 41.75 21.20 6,749.62 6,589.62 3,775.10 1,532.56 2,503,236.85 215,798.63 1.34 4,064.03 NSG-CT_D/P(1) 8,175.00 41.95 21.38 6,768.25 6,608.25 3,790.64 1,538.62 2,503,252.24 215,805.06 0.93 4,080.68 NSG-CT_D/P(1) 8,200.00 41.84 21.09 6,786.86 6,626.86 3,806.20 1,544.67 2,503,267.65 215,811.49 0.89 4,097.35 NSG-CT_D/P(1) 8,225.00 41.34 21.31 6,805.55 6,645.55 3,821.68 1,550.67 2,503,282.97 215,817.86 2.08 4,113.91 NSG-CT_D/P(1) 8,250.00 41.43 21.52 6,824.31 6,664.31 3,837.06 1,556.70 2,503,298.20 215,824.27 0.66 4,130.41 NSG-CT_D/P(1) 5/17/2017 12:01:45PM Page 10 COMPASS 5000.1 Build 81 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,275.00 41.37 21.68 6,843.06 6,683.06 3,852.43 1,562.79 2,503,313.42 215,830.73 0.49 4,146.91 NSG-CT_D/P(1) 8,300.00 41.23 22.26 6,861.85 6,701.85 3,867.74 1,568.96 2,503,328.57 215,837.28 1.63 4,163.37 NSG-CT_D/P(1) 8,325.00 40.96 22.26 6,880.69 6,720.69 3,882.94 1,575.19 2,503,343.62 215,843.87 1.08 4,179.76 NSG-CT_D/P(1) 8,350.00 40.49 22.20 6,899.63 6,739.63 3,898.04 1,581.36 2,503,358.56 215,850.41 1.89 4,196.03 NSG-CT_D/P(1) 8,375.00 40.18 22.47 6,918.69 6,758.69 3,913.01 1,587.51 2,503,373.38 215,856.92 1.42 4,212.16 NSG-CT_D/P(1) 8,400.00 40.57 22.31 6,937.73 6,777.73 3,927.98 1,593.68 2,503,388.20 215,863.46 1.61 4,228.31 NSG-CT_D/P(1) 8,425.00 40.58 22.39 6,956.72 6,796.72 3,943.02 1,599.86 2,503,403.08 215,870.01 0.21 4,244.53 NSG-CT_D/P(1) 8,450.00 40.65 22.07 6,975.70 6,815.70 3,958.09 1,606.02 2,503,417.99 215,876.53 0.88 4,260.76 NSG-CT_D/P(1) 8,461.00 40.39 21.97 6,984.06 6,824.06 3,964.71 1,608.70 2,503,424.55 215,879.37 2.44 4,267.89 NSG-CT_D/P(1) 8,530.00 40.47 20.98 7,036.59 6,876.59 4,006.35 1,625.08 2,503,465.77 215,896.76 0.94 4,312.55 NSG_WL(2) 8,550.00 40.43 21.23 7,051.81 6,891.81 4,018.46 1,629.75 2,503,477.76 215,901.73 0.84 4,325.51 MWD_InterpAzi+sag(3) 8,582.94 40.40 20.23 7,076.89 6,916.89 4,038.43 1,637.31 2,503,497.54 215,909.77 1.97 4,346.84 MWD_InterpAzi+sag(3) 8,679.42 36.10 16.93 7,152.64 6,992.64 4,094.99 1,656.41 2,503,553.62 215,930.25 4.93 4,406.53 MWD_InterpAzi+sag(3) 8,773.69 31.25 12.83 7,231.08 7,071.08 4,145.44 1,669.94 2,503,603.72 215,945.00 5.68 4,458.69 MWD_Interp Azi+sag(3) 8,868.60 25.32 7.14 7,314.64 7,154.64 4,189.63 1,677.93 2,503,647.70 215,954.08 6.86 4,503.19 MWD+SC+sag(4) 8,962.24 19.34 3.86 7,401.22 7,241.22 4,225.00 1,681.47 2,503,682.98 215,958.47 6.52 4,537.92 MWD+SC+sag(4) 9,057.87 18.75 2.70 7,491.61 7,331.61 4,256.15 1,683.26 2,503,714.08 215,961.02 0.73 4,568.10 MWD+SC+sag(4) 9,151.86 14.64 355.70 7,581.63 7,421.63 4,283.10 1,683.08 2,503,741.02 215,961.50 4.86 4,593.67 MWD+SC+sag(4) 9,246.54 9.39 338.94 7,674.23 7,514.23 4,302.26 1,679.40 2,503,760.26 215,958.30 6.60 4,610.75 MWD+SC+sag(4) 9,342.11 8.42 342.34 7,768.65 7,608.65 4,316.20 1,674.48 2,503,774.32 215,953.71 1.15 4,622.48 MWD+SC+sag(4) 9,437.15 10.00 349.64 7,862.47 7,702.47 4,330.95 1,670.89 2,503,789.15 215,950.48 2.06 4,635.40 MWD+SC+sag(4) 9,530.93 10.03 348.31 7,954.82 7,794.82 4,346.96 1,667.77 2,503,805.23 215,947.75 0.25 4,649.65 MWD+SC+sag(4) 9,625.23 9.60 346.92 8,047.74 7,887.74 4,362.66 1,664.32 2,503,821.01 215,944.69 0.52 4,663.52 MWD+SC+sag(4) 9,720.25 8.88 348.36 8,141.52 7,981.52 4,377.56 1,661.05 2,503,835.99 215,941.78 0.80 4,676.68 MWD+SC+sag(4) 9,815.48 9.13 353.46 8,235.58 8,075.58 4,392.26 1,658.71 2,503,850.75 215,939.80 0.88 4,689.94 MWD+SC+sag(4) 9,909.75 10.54 354.70 8,328.46 8,168.46 4,408.28 1,657.06 2,503,866.80 215,938.54 1.51 4,704.66 MWD+SC+sag(4) 10,006.30 10.87 356.47 8,423.33 8,263.33 4,426.16 1,655.68 2,503,884.70 215,937.60 0.48 4,721.23 MWD+SC+sag(4) 10,098.04 9.43 349.34 8,513.64 8,353.64 4,442.18 1,653.76 2,503,900.77 215,936.07 2.08 4,735.87 MWD+SC+sag(4) 10,192.62 9.90 345.42 8,606.88 8,446.88 4,457.66 1,650.28 2,503,916.33 215,932.97 0.85 4,749.52 MWD+SC+sag(4) 10,288.78 11.34 343.58 8,701.39 8,541.39 4,474.73 1,645.53 2,503,933.51 215,928.64 1.54 4,764.28 MWD+SC+sag(4) 10,382.97 12.96 346.09 8,793.46 8,633.46 4,493.87 1,640.37 2,503,952.77 215,923.95 1.81 4,780.88 MWD+SC+sag(4) 10,477.69 16.55 355.15 8,885.06 8,725.06 4,517.63 1,636.67 2,503,976.61 215,920.83 4.49 4,802.34 MWD+SC+sag(4) 10,573.63 20.68 0.52 8,975.97 8,815.97 4,548.20 1,635.67 2,504,007.20 215,920.58 4.66 4,831.10 MWD+SC+sag(4) 10,668.03 23.42 5.56 9,063.46 8,903.46 4,583.55 1,637.64 2,504,042.49 215,923.41 3.52 4,865.33 MWD+SC+sag(4) 10,763.15 29.93 6.12 9,148.41 8,988.41 4,626.01 1,642.01 2,504,084.83 215,928.81 6.85 4,907.05 MWD+SC+sag(4) 10,856.33 36.45 7.83 9,226.35 9,066.35 4,676.60 1,648.26. 2,504,135.25 215,936.30 7.07 4,957.09 MWD+SC+sag(4) 10,952.57 42.68 10.01 9,300.51 9,140.51 4,737.11 1,657.84 2,504,195.51 215,947.35 6.63 5,017.60 MWD+SC+sag(4) 11,046.29 49.45 12.89 9,365.50 9,205.50 4,803.18 1,671.32 2,504,261.23 215,962.44 7.55 5,084.60 MWD+SC+sag(4) 11,141.82 55.06 13.96 9,423.96 9,263.96 4,876.62 1,688.88 2,504,334.22 215,981.78 5.94 5,159.87 MWD+SC+sag(4) 11,237.79 63.09 14.66 9,473.24 9,313.24 4,956.32 1,709.23 2,504,413.40 216,004.08 8.39 5,241.96 MWD+SC+sag(4) 5/17/2017 12:01:45PM Page 11 COMPASS 5000.1 Build 81 • 0 Halliburton Definitive Survey Report Company: Hilcorp Alaska,LLC Local Co-ordinate Reference: Well Trading Bay Unit M-28RD Project: McArthur River Field TVD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead MD Reference: TBU M-28A Plan @ 160.00usft Well: Trading Bay Unit M-28RD North Reference: True Wellbore: M-28RD Survey Calculation Method: Minimum Curvature Design: M-28RD Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,331.93 68.09 14.75 9,512.13 9,352.13 5,039.21 1,730.98 2,504,495.73 216,027.85 5.31 5,327.51 MWD+SC+sag(4) 11,427.84 75.14 12.72 9,542.37 9,382.37 5,127.57 1,752.55 2,504,583.54 216,051.56 7.62 5,418.21 MWD+SC+sag(4) 11,521.11 75.55 9.69 9,565.97 9,405.97 5,216.08 1,770.08 2,504,671.59 216,071.25 3.17 5,507.79 MWD+SC+sag(4) 11,616.08 75.36 8.76 9,589.82 9,429.82 5,306.81 1,784.81 2,504,761.94 216,088.19 0.97 5,598.64 MWD+SC+sag(4) 11,710.57 75.10 9.22 9,613.91 9,453.91 5,397.06 1,799.09 2,504,851.81 216,104.67 0.55 5,688.87 MWD+SC+sag(4) 11,804.69 75.30 10.09 9,637.95 9,477.95 5,486.76 1,814.35 2,504,941.11 216,122.12 0.92 5,778.90 MWD+SC+sag(4) 11,894.19 78.16 10.40 9,658.50 9,498.50 5,572.48 1,829.84 2,505,026.42 216,139.70 3.21 5,865.20 MWD+SC+sag(4) 11,993.11 81.06 11.20 9,676.33 9,516.33 5,668.04 1,848.08 2,505,121.51 216,160.26 3.04 5,961.72 MWD+SC+sag(4) 12,087.81 81.98 11.92 9,690.30 9,530.30 5,759.80 1,866.85 2,505,212.79 216,181.26 1.23 6,054.78 MWD+SC+sag(4) 12,182.81 82.04 14.73 9,703.51 9,543.51 5,851.34 1,888.53 2,505,303.77 216,205.17 2.93 6,148.54 MWD+SC+sag(4) 12,278.59 81.91 14.85 9,716.88 9,556.88 5,943.04 1,912.74 2,505,394.85 216,231.61 0.18 6,243.23 MWD+SC+sag(4) 12,372.05 82.05 16.86 9,729.92 9,569.92 6,032.06 1,938.02. 2,505,483.22 216,259.06 2.13 6,335.70 MWD+SC+sag(4) 12,466.35 83.48 18.84 9,741.80 9,581.80 6,121.10 1,966.70 2,505,571.53 216,289.90 2.58 6,429.24 MWD+SC+sag(4) 12,561.35 82.66 18.47 9,753.26 9,593.26 6,210.45 1,996.86 2,505,660.12 216,322.24 0.95 6,523.54 MWD+SC+sag(4) 12,656.09 82.91 19.86 9,765.16 9,605.16 6,299.23 2,027.72 2,505,748.12 216,355.25 1.48 6,617.51 MWD+SC+sag(4) 12,751.70 82.41 20.91 9,777.37 9,617,37 6,388.11 2,060.75 2,505,836.17 216,390.44 1.21 6,712.26 MWD+SC+sag(4) 12,846.18 83.10 19.88 9,789.29 9,629.29 6,475.96 2,093.41 2,505,923.20 216,425.24 1.30 6,805.90 MWD+SC+sag(4) 12,940.68 82.85 20.82 9,800.84 9,640.84 6,563.90 2,126.02 2,506,010.31 216,459.99 1.02 6,899.61 MWD+SC+sag(4) 13,035.69 81.97 18.73 9,813.40 9,653.40 6,652.51 . 2,157.89 2,506,098.12 216,494.01 2.37 6,993.74 MWD+SC+sag(4) 13,130.34 83.04 17.71 9,825.74 9,665.74 6,741.65 2,187.23 2,506,186.51 216,525.51 1.56 7,087.58 MWD+SC+sag(4) 13,225.54 82.41 18.88 9,837.80 9,677.80 6,831.31 2,216.87 2,506,275.42 216,557.33 1.39 7,182.01 MWD+SC+sag(4) 13,320.16 83.35 17.89 9,849.53 9,689.53 6,920.40 2,246.48 2,506,363.76 216,589.11 1.44 7,275.89 MWD+SC+sag(4) 13,414.18 83.66 19.15 9,860.16 9,700.16 7,008.98 2,276.15 2,506,451.59 216,620.94 1.37 7,369.30 MWD+SC+sag(4) 13,508.55 82.35 17.28 9,871.65 9,711.65 7,097.95 2,305.43 2,506,539.82 216,652.38 2.41 7,462.96 MWD+SC+sag(4) 13,636.00 82.35 17.28 9,888.62 9,728.62 7,218.56 2,342.95 2,506,659.48 216,692.83 0.00 7,589.27 PROJECTED to TD mitchell.laird@halliburton.com Michael Calk ins.,`"' � Checked By: 2017.05.1709:39:46-08'00' Approved By: M„ .� '" Date: 5/17/2017 5/17/2017 12:01:45PM Page 12 COMPASS 5000.1 Build 81 • i Hilcorp Energy Company CASING &CEMENTING REPORT Lease&Well No. MRF M-28RD Date Run 16-May-17 County CIO State Alaska Supv. Evan K.Harness/Harold Soule CASING RECORD Liner V' TD 13,636.00 Shoe Depth: PBTD: Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Shoe 7 29.0 L-80 DWC/C VAM 1.80 13,636.00 13,634.20 1 Jt 7 29.0 L-80 DWC/C 38.41 13,634.20 13,595.79 Flt Clr 7 29.0 L-80 DWC/C 1.40 13,595.79 13,594.39 2 JT 7 29.0 L-80 DWC/C 38.27 13,594.39 13,556.12 3 Jt w/LC 7 29.0 L-80 DWC/C 39.90 13,556.12 . 13,516.22 127 JT 7 29.0 L-80 DWC/C 5,187.42 13,516.22 8,328.80 PUP 7 29.0 L-80 DWC/C 5.44 8,328.80 8,323.36 Liner hanger 29.0 L-80 DWC/C 23.70 8,323.36 8,299.66 CEMENTING REPORT Shoe @ 13636 FC @ 13,594.00 Top of Liner 8300 Preflush(Spacer) Type: Mud Push 2 Density(ppg) 12.5 Volume pumped(BBLs) 15 Lead Slurry Type: Easy Block Sacks: 544 Yield: 1.34 Density(ppg) 15.3 Volume pumped(BBLs) 130 Mixing/Pumping Rate(bpm): 3 Tail Slurry w Type: Sacks: Yield: F Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): w Post Flush(Spacer) 1- re Type: Density(ppg) Rate(bpm): Volume: U- Displacement: Type: OBM Density(ppg) 9.6 Rate(bpm): 5 Volume(actual/calculated): 335/338 FCP(psi): 960 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1500 Casing Rotated? Yes X No Reciprocated? X Yes No %Retums during job 100 Cement returns to surface? Yes X No Spacer returns? X Yes No Vol to Surf: 2 Cement In Place At: 21:12 Date: 5/15/2017 Estimated TOC: 9,852 Method Used To Determine TOC: cal CB.- .CA-.i t°L *.. jaAco,--°13 :: - .f 1.7,,...,> 13cC>4' -T 7-6 Post Job Calculations: ,1 Calculated Cmt Vol @ 0%excess: 125 Total Volume cmt Pumped: 130 ` ,i7 Cmt returned to surface: 2 Calculated cement left in wellbore: 128 OH volume Calculated: 85.46 OH volume actual: Actual%Washout: www.wellez.net WellEz Information Management LLC ver_102716bf • • M-28RD Days vs Depth 0 . - - 500 —M-28RD Plan 1000 --.0—.M-28RD Actual 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 a 7000 7500 v L 8000 rtsa) 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 0 5 10 15 20 25 30 35 40 Days 6/21/2017 5:08 PM 6)u-4-021a bra Oudean Hilcorp Alaska, L GeoTech II 3800 Centerpoint Drive, Suite 100 — �/ Anchorage, AK 99503 Tele: 907 777-8337 Ifilenr1,. laMku.Lf.{: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 6/01/2016 RECEIVED To: Alaska Oil & Gas Conservation Commission MAY 3`1 2017 Meredith Guhl, Petroleum Geology Assistant 333 W. 7th Ave. Ste#100 AOGCC Anchorage, AK 99501 DATA TRANSMITTAL M-28 RD 217-026 Transmitted herewith are cuttings from K-10RD2 WELL BOX SAMPLE INTERVAL; M-28RD BOX 1 OF 4 8550' - 9780' BOX 2 OF 4 9780' - 11080' BOX 3 OF 4 11080' - 12360' BOX 4 OF 4 12360' - 13631' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Receives B • 0 . Date: r - - tior 1.4 9\ 1//7, ,s. THE STATE Alaska Oil and Gas o e LAsKAConservation Commission fA 'it th 333 West Seventh Avenue 113 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4,A��,410" Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, West Foreland Oil Pool, TBU M-28RD Permit to Drill Number: 217-026 Sundry Number: 317-129 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. o ster , , Chair DATED this ft' �-y of May, 2017. RBDMS C i 1 6 2017 • ‘3.(-,0151, �I►��t'1 ECEIVED STATE OF ALASKA MAR 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0. 217-026 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic IDService ❑ 6.API Number: Anchorage,AK 99503 50-733-20414-01 • 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No 0 / Trading Bay Unit M-28RD ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730/ADL017594(Proposed) McArthur River Field/West Foreland Oil Pool(Proposed)• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ±13,880(Proposed) ±9,924(Proposed) ±13,800(Proposed) ±9,914(Proposed) 3,224 psi N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 990' 26" 990' 990' Surface 1,445' 16" 1,445' 1,443' 2,630 psi 1,020 psi Intermediate 4,590' 13-3/8" 4,590' 4,031' 3,090 psi 1,540 psi Production 497' 10-3/4" 497' 497' 5,860 psi 3,220 psi Production ±8,003(proposed) 9-5/8" ±8,500(proposed) ±7,017(proposed) 6,870 psi 4,760 psi Liner ±5,580(proposed) 7" ±13,880(proposed) ±9,924(proposed) 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/1/2017 OIL 0. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature 5 -r3tyLN Phone (907)777-8356 Date 3'2.e./ 2Oi, COMMISSION USE ONLY Conditions of approval: Notify Com fission so that a representative may witness Sundry Number: 3 17— /2_ Plug Integrity ❑ BOP Testi Mechanical Integrity Test ❑ Location Clearance ❑ 4445 1.1.7 5 1 .. 113 Other: 3 go ' -7,j't" v/} RBDMS ` Iv f�I U 2017 lc Ale, - Fze.., /..,,,-- ,:p -4,4-4-.1_ ii•I C..7 '.1.- ; (i‘Z^.•-.'.5 Post Initial Injection MIT Req'd? Yes ❑ No ❑ ) Spacing Exception Required? Yes ❑ No [r Subsequent Form Required: ' -- 0 7 ( �/e_i( �`C"'~� � W AAPPROVED BY Approved by: 9,2,,,,/,___ COMMISSIONER THE COMMISSION Date: 3 _/2 _/ 7 toi 313 ORrLGNtAsL - / SubmFormand Form 10-403 Revised 11/2015 valplid for 12 months from the date of approval. Attachments in Duplicate • 111 Well Work Prognosis Well: M-28RD PTD: 217-026 Hilcarp Alaska,LLC. Date: 03/22/2017 Well Name: M-28rd API Number: 50-733-20414-01 Current Status: Sidetracked Producer Leg: B-1 Estimated Start Date: June 01, 2017 Rig: Steelhead Rig#51 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 217-026 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) Current Bottom Hole Pressure: 4,190 psi @ 9,658'TVD 0.434 lbs/ft(8.34 ppg)based on offset producers Maximum Expected BHP: 4,190 psi @ 9,658'TVD 0.434 lbs/ft(8.34 ppg)based on offset producers Maximum Potential Surface Pressure:3,224 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary f M-28rd is a West Foreland only producer that will be completed with an ESP. This new well was side tracked from the current M-28 which was comingled G and Hemlock producer.This workover will perforate and run the completion string in the new well. Last Casing Test: Casing and liner tested to 2,500 psi under PTD 217-026 Procedure: 1. ***Take over operations from the Drilling Sidetrack Program *** 2. Test BOP to 250psi low/3,500psi high. (Note: Notify AOGC.,5 48 hours in advance of test to allow them to witness test). (ZP'� �K"` `� -- 3. Workover fluids will be 6% KCL. BOP's will be closed as needed to circulate the well. A 4. Rig up E-Line and run cased hole logging suite. POOH. (CAL =7 �zyv,�^,r: r d3- / O4 5. PU TCP guns, RIH and perforate per program. 6. After detonation, circulate out any perf gas, confirm well is static, POOH. 7. PU and run ESP completion. • A high set packer, packer vent valve, and SSSV will be ran if well indicates ability to flow to surface. 8. If applicable-Set and test packer to 1,500 psig charting for 30 minutes. 9. Set BPV. NU tree,test same. 10. Turn well over to production 11. Schedule SVS testing with AOGCC as per regulations. 12. If applicable (no packer and SSSV installed in step 7)-Schedule no-flow with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Proposed 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • �i c) McArthur River Field �11 ) ea®1 Steelhead Platform PROPOSED �r"� Well: PTD: 17-026 1 API:50-733-20414-017-02 _1 Hilrarp Alaska.LLA: Last Completed: Future S '�v RKB-to TBG Head:71.4' l CASING DETAIL 1 ...122L SIZE W7 GRADE CONN ID TOP BOTTOM 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress 15.124" Surf 1,447' 26" 13-3/8" 61 K-55 Buttress 12.515" Surf 2,563' CTC 68 K-55 Buttress 12.415" 2,563' 4,590' Packer L16" 10-3/4" 51 N-80 Buttress 9.850" Surf 368' 2,003' 55.5 N-80 Buttress 9.760" 368' 497' 447 N-80 Buttress 8.681" 497' 5,289' 9 5/8 47 S-95 Buttress 8.681" 5,289' 8,550'(TOW) 13-3/8" 29 L-80 DWC/C 6.184' ±8,350' ±13,64:, Tubing Detail 6.4 L-80 I 8rnd EUE I 2.441" Surf ±11,600 JEWELRY DETAIL No Depth Depth iJ OD Item MD TVD 71.4' 71.4' Tubing Hanger 1 ±450' ±450' 1.31 itingent-SSSV 2 ±480' ±480' Contingent-ESP Dual Packer w/WFT vent valve Liner Hanger 3 11,400' ±9,539' -'_31 X-nipple ±8,350' Discharge,Bolt-On Min 6.059" 26 Pump Seals A Motors 8-1/2"TOW 9-5/8" 11,800' ±9,637' N/A Centralizer Anode 8,550' x 3 **Note-Straight Hole Pump Tangent Section 11,521'to 11,804' IIIip a(dS PERFORATION DATA 4 'I-D` Zone Top Btm Top Btm ' tii4 (MD) (MD) (TVD) (TVD) Date WF-1 ±11,842' ±12,148' ±9,647' ±9,699 Future WF-1 ±12,169' ±12,323' ±9,702' ±9,723' ±154 6 Future Status Pe+" Feet SFE ts WF-2 ±12,424' ±12,481' ±9,737' ±9,744' ±57' 6 future �C WF-2 ±12,518' ±12,551' ±9,748' ±9,752' ±33' 6 e WF-1WF-2 ±12,563' ±12,590' ±9,754' ±9,757' ±27' 6 uture Future Future Future WF-2 ±12,645' ±12,658' ±9,764' ±9,766' ±13' 6 WF-2 ±12,704' ±12,860' ±9,771' ±9,791' ±156' 6 WF-2 ±12,891' ±13,017' ±9,795' ±9,811' ±126' 6 WF-2 WF-2 ±13,160' ±13,290' ±9,830' ±9,846' t130' 6 Future 1 PBTD=#13,500' TD=13,640' MAX HOLE ANGLE=83.66° Updated by:DEM 05/10/2017 • McArthur River Field , II Well: M-28RD PROPOSED API #: 50-733-20414-01 IIiicorp Alaska,LLC PTD: 217-026 RKB to Sea Level(MSL)=160' i "'`X'° i'.. CASING DETAIL (f."/ i SIZE WT GRADE CONN ID TOP BTM. .r ' '71 26" 267/397 Dril-Quip Surf 990' *"- x.� 16" 75 K-55 Buttress Surf 1,445' " 13-3/8" 61/68 K-55 Buttress 12.415" Surf 4,590' ri, 10-3/4" 51/55 N-80 Buttress 9.604" Surf 497' `t ;11)4 9-5/8" 47 N-80 Buttress 8.681" 497' 8,500' (TOW) ' ,xlk;,�It + 9 a� 4. f 1L y7; g4 I JEWELRY DETAIL Depth SDD Liner `° No Depth(MD) (TVD) ID Item H8a ± ,300' 00 '•Izii e 01 ±8,300' ±6,797' 6.059" SDD Baker Liner Hanger sel 2 ±8,500' ±7,017' - KOP " ' .' 3 ±8300'- ',880' ±9,814' 6.059" 7" 29#L-80 DWC/C 8-1/2" „ . Window ., „7 2 ±8,500' / 3 / r // J Q CEMENT DETAIL It1 f.14 .4 TOC Depth TOC Depth 4,- 4,,, No Volume Item ;a �9 4 (MD) (TVD) ' ` k.` 4 ±10,000' ±8,422' 132 bbls 15.3 ppg Class G cement w/%2 bbl t cemnet LCM c TD=13,880' PBTD=13,800' Max Hole Angle=83° Updated By:MMM 2/14/17 • • McArthur River Field ' Steelhead Platform Well: M 28rd PROPOSED PTD:217-026 API:50-733-20414-01 Il:ilcorp Alaska,LLC Last Completed: Future RKB-to TBG Head:71.4' L LL CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BOTTOM 26" 2566711///53658977 Dril Quip Surf 990' 2 26" 16" _ 75 K-55 Buttress 15.124" _ Surf 1,445' 4,590' NEM 13-3/8" K 55 Buttress 12.415" Surf 10 3/4 N-80 Buttress 9.604" _ Surf 497' E. E 16" 9-5/8" 47 N-80 Buttress 8.681" 497' ±8,500' (TOW) A I. 7" ,, DWC/C 6.184" ±8,300' ±13,880' 13-3/8" Tubing Detail 2-7/8" 6.4 L-80 8rnd EUE 2.441" Surf ±11,430' JEWELRY DETAIL No Depth Depth ID OD Item MD TVD 71.4' 71.4' Tubing Hanger 1 ±450' ±450' 2.313" Contingent—SSSV 2 ±480' ±480' Contingent—ESP Dual Packer w/WFTventvalve 3 ±11,400' ±9,539' X-nipple ) Discharge,Bolt-On Liner Ha n@ Pump ±8,300• 4 Seals Min 6.059IO Motors ±11,600' ±9,593' N/A Centralizer Anode A 8-1/2"TOW 9-5/8" ±8,500• , 3 11 PERFORATION DATA 4 Top Btm Top Btm _ Feet SPF Date Status It Zone (MD) (MD) (TVD) (TVD) WF-1 ±11,858' ±9,659' Future WF-2 ±12,349' ±9,733' Future WF-1 WF-2 PBTD=±13,800' TD=±13,880' MAX HOLE ANGLE=±83° Updated by:JLL 03/27/2017 • • Steelhead Platform . 11 M-28 Current & Proposed Hilrurp masks,Luc Steelhead Platform Tubing hanger,McEvoy SL- M-28 EP-ESP,13 5/8 X 4%IBT lift 26 X16 X133/8X103/4 X and susp,W/4"Type HBPV 41/2 profile,2-3/8 continuous control lines BHTA,FMC,8-11-A0, 41/165M FE aati_iu it Valve,Swab,FMC-120, O'�'�'� 41/165M FE,HWO,DO >♦ „_, lar. IIID? Valve,upper master, . WKM-M,SSV,41/165M FE, �� I ®p , w/18"Omni operator,EE y ei•., Valve,wing FMC-120, ,I 41/165M FE,HWO,DD 01O Valve,Master,FMC-120, f 41/16 5M FE,HWO,DD l� 0 , Vie• IMF i {w Ila- A WI 1! II MI Tubing head,McEvoy SL-P,135/85M FE top X 16%5M FE bottom, _ w/2-21/365M SSO .p ; ».e_ lift '74:111111.1., Tubing head,FMC-TC-60,spec for .. os �41 .41 unihead,16%SM FE top X 16%5M _ Odd bottom,w/2-21/16 SM 55O , Unihead,FMC Type 2,16%SM - = Valve,FMC-120, 2 1/165M FE,HWO,AA FE top X 21%2M FMC speedlock bottom,w/4-21/16 5M 55O 1II. ei•1011,1 Adapter spool,FMC-4-5-S 30"MSS E ' tr.e.:,''.,1r1 ila t 777A'''���777 , stdd bottom X21%2M FMC , _ ,`i . speedlock top,w/2-2"LPO Starting head,FMC,30"MSS a -I FE%26"butt weld �ILa.. I. ■I 26" 16" 13 3/8" 9 5/8" 4 1/2 • • Steelhead Platform 13 5/8 5M BOP (Oil Leg) 01/30/2017 Nilcorp Also.1.1.1: Rig floor Bottom of drip pan 6.75' 22"X 16"for air boot sleeve, 19'in length 10.92' 26.23' Moon pool deck to rig floor III 11111,111 11 • 1111 off 4.54' • Hydril Ic 135/8-5000 it iir iitrirtit �I a Ifl I!'5!'5!' it 4_, C u . 4.67' 0 Trl rfi filvrtkt • Top of Moonpool Moonpool deck top@ 55.95' deck 55.38' 9.6o' 1.1 _µms 4 Total BOP assembly l_l 1.T3. .' � 101 2.26' • 1!1 !r 'CIW4J , 5t 1f++ 2.83' 411 ill r i l III r i 1.25' ill trl l❑1❑III' -- ---- 3.86'flange above rig sub grating Rig sub grating Upper Wellhead Roo to Rig Sub Grating 23.47' 5.08'clamp above floor Upper wellhead room floor Wellhead floor to Upper Wellhead Roo 22.88' li ❑i V Top of wellhead • • • ialsna sd9 1-1.- A UN U v _Nix W DI 4,U 2 O �a 0_ ° o U Y U N i[1 co (D cC W D4 D4 D4 < 0 U a N M1 O La VD O0 _� ! 1 LL 0 Z#NNV1 dlbl U U v L ►1 /1 ► o �#NNV1 c1111 0z i Q NN U Q LL P\-\' (=i) F- 0- 0_ d Q m m 4 w rew Li 0 _ . c = D4 D4 :Ily W • Y uj 1 ,7i, V W v N D I— w O Q BU U� CO CO COII—^^ _ 0 l^ v) 0_ J co D 0- 0 U 0 W 0 ir U O U a w N 0 oil 4)4 N • Steelhead Rig#51 BOP Test Procedure �i��rp Alaska.l,l.c Attachment#1 tt Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Steelhead Rig # 51 WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Production Vessel that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Circulate down tubing taking returns to production off of the annulus and sweep gas and oil to production until returns are clean. 4) Confirm that well is static Monitoring for any pressure Build Up Or if Well Is Still On A Strong Vacuum ( I do not think that We Often Shoot Fluid Levels) Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV, ND Tree 2) Clean/Inspect/And Confirm By Screwing Into Lift Threads (Counting Turns) Remove Sub—Check all Lock Down Pins to Ensure they Will Back Out Far Enough To Clear Hanger—Plug Penetrations Through Hanger—Put a Sealing Cap On Penetrator—Leave BPV Installed & If Needed Install Adaptor to Test Joint, Might Be Using a Left Hand Blank Ported Sub or a Combo Tool Of Various Types NU BOP. 3) MU landing joint With On/Off Tool Adaptor. 4) Set slips, mark same. Test per standard Steelhead Rig#51 Test Procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, establish static fluid level. 2) Once the fluid level is established to be static, notify Hilcorp Anchorage Operations Engineer. 3) Proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a BPV, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) MU Left Hand Blanking Plug d) Plug penetrations in hanger. For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 4) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC-guy.schwartz@alaska.gov) and Mr. • • Steelhead Rig#51 BOP Test Procedure Hii,o�,P Alaska,LIS' Attachment#1 Jim Regg (AOGCC-jim.regg@alaska.gov)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 6) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Note: BOPE high test pressures will be determined upon Approved Sundry.Test joint sizes will be determined upon well work. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Pull Wear Bushing, Make up Test Plug and Test Joint—Land Same Measuring in the hole getting a Good Mark when Landed . a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after Isolation Plug is Set) 1) Make up Test Joint as per diagram. Insure all connections above test plug are torque. 2) Pull Wear Bushing and install Test Plug 3) Make up Side-Entry Sub, (2)TIW valves and IBOP to top of Test Jt. 4) Make up Test Hose#1 to Side-Entry Sub and Test Hose#2 to Top Drive Test Sub. 5) Verify Annulus valve is open and monitored. 6) Fill BOP and Choke Manifold with water. Purge air from system through Choke manifold top valve and IBOP. • • Steelhead Rig#51 BOP Test Procedure wieorp ailska,1��. Attachment#1 7) Close Annular and set closing pressure to 800 psi. (pressure can be increased as necessary to seal element) Perform full body BOP test to check integrity of system. Note: When testing, pressure up with pump to desired pressure, close MP1 and/or MP2 to trap pressure and read same with chart recorder. 8) Referencing the attached schematics test BOP as per Permit and Regulations as follows. a) Close W1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Open W1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Flow Diagram) d) Test#1-Annular, IBOP, Upper TD Valve, Kill Line Demco, C1, C2, C3, C12, C13, C14. e) Test#2—Test VBRs,Top TIW, Lower TD valve, HCR2, C4, C5, C6. f) Test#3—Test VBRs, W2, C7, C8, C9 g) Test#4.—Test Lower Pipe Rams, Bottom TIW. h) STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (I.E. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. j) Back out Test joint and pull to rig floor. Connect test hose to C13. Pressure up on Manual and Hydraulic Chokes to 1,000 psi. Function Chokes to bleed pressure and verify operation. k) Test#5. —Test Blinds and C10, C11. I) Make up 2nd Test Joint if running two string sizes m) RIH with 2nd Test Joint and test plug. Make up Side-Entry Sub, (1)TIW valve and IBOP to Test Joint. Connect#1 Test Hose to Side-Entry Sub and #2 Test Hose to suspended TIW w/test sub. • • Steelhead Rig#51 BOP Test Procedure Hileorp Alaska,IlkAttachment#1 Purge air from system. (always verify lengths needed when compared to RKB and add pups if necessary) n) Test#6-Test Annular, IBOP, suspended TIW and HCR1. o) Test#7-Test VBRs, Upper TIW and Manual Choke. p) Rig down test equipment. Blow down lines. Close Annulus valve. Pull test plug. Install Wear Bushing. Rig down, or stand back Test Stand. q) Back out test joint& pull, close blinds, close valves C7, C8, C9, open HCR1, and W1 r) Open all rams and annular and close HCR2 to place BOPE back into operating position for well work. s) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. 0 • c CD CD 0 � a / >' � 2 o Q _ ■ a ■ §\ F % o ■/ 2k�.o / « �§E ® E 0c ) \ § 2 0. c / < _ / / 7 > 73 f2a /.§ 00 § .\ n -a 0 o 0 0 2 2 2 # $ C 2 � o c E\ 2 I / CD / U45 / / 5 1:11 0 > o I- a. / / Q \ a o c > ° 0 2 § CO 0 k Cil $f A co c .cO \ C) k \ � k 0 2 E § ° & a R o 2 O 2 0 .g a -t 2 - / L -'(3 L. \ / § c \ / 2 : 7 / 0 2 I CX t \ 04 co 2 0 $ k a Q / \ CI 0 ca o 4 o x % t E 0. 2 * ct k >< � .2 C 0 E k .o 0 0- 0 7 0 � � / � 2 it a p .. _ % \ U ° 0 ~ ili 2 f 0 u \ \ 0 3 / \ / ¢ o_ �i • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, May 10, 2017 1:17 PM To: Schwartz,Guy L(DOA) Cc: Juanita Lovett; Stan Golis Subject: M-28RD PTD 217-026 Attachments: 10-403 M-28RD 2017-03-28 Submitted.pdf; M-28rd Proposed 2017-05-10.pdf Guy We called TD on M-28rd this morning at 13,639.56'. Attached is an updated schematic showing our perf selection. We hope to be ready to transition to the completion permit early next week thanks Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe(c�hilcorp.com Hilcorp A Company Built on Energy 1 • OF T • '��s� THE STATE Alaska Oil and Gas of SKA Conservation Commission = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Monty Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503-5832 Re: McArthur River Field, West Foreland Oil Pool, TBU M-28RD Hilcorp Alaska, LLC Permit to Drill Number: 217-026 Surface Location: 970' FNL, 532' FWL, Sec. 33, T9N, R13W, SM,AK Bottomhole Location: 1201' FSL, 2276' FEL, Sec. 21, T9N, R13W, SM,AK Dear Mr. Myers: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition,the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20,Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05,Title 20,Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /C)4-e-cc Cathy . Foerster Chair DATED this(p day of March, 2017. ritULIVtU STATE OF ALASKA FEB 2 4 2017 AllIA OIL AND GAS CONSERVATION COMNIN PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp [] lc.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil E. Service- Winj ❑ Single Zone [ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑, • Reentry❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone LI 012)Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ ' Single Well ❑ 11.Well Name and Number: *�i Hilcorp Alaska,LLC Bond No. 022035244 • 7$tx M M-28RD �^O 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Anchorage,AK 99503 MD: 13,880' TVD: 9,924' , McArthur River Field 4a. Locations 4\\y(ell(GT/Ili-rental Section): 7.Property Designation(Lease Number): West Foreland Oil Pool Surface: If&FNL, FWL,Sec 33,T9N,R13W,SM,AK (SHL,TPH)ADL 018730/(BHL)ADL 017594, 141n1a t;( iiij Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1706'FNL,2227'FWL,Sec 28,T9N,R13W,SM,AK N/A 3/24/2017 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1201'FSL,2276'FEL,Sec 21,T9N,R13W,SM,AK 8956 Acres , 10,972'to nearest unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 160' - 15.Distance to Nearest Well Open Surface: x-214174 y- 2499500 Zone-4 k GL Elevation above MSL(ft): N/A to Same Pool: 1357'to K-30 16.Deviated wells: Kickoff depth: 8500 feet , 17.Maximum Potential Pressures in psig(see 20 AAC 25.0p. Maximum Hole Angle: 82.85 degrees , Downhole: 4748 • Surface: 2504 'c„ 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 8-1/2" 7" 29# L-80 DWC/C 5,580' 8,300' 6,865' 13,880' 9,924' 758 ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): 13,000' 10,797' N/A 11,665' 9,533' 11,655' Casing Length Size Cement Volume MD TVD Conductor/Structural 990' 26" 990' 989' Surface 1445' 16" 1800 sx 1445' 1442' Intermediate 4590' 13-3/8" 2900 sx 4590' 4031' Production 497' 10-3/4" 497' 496' Production 10902' 9-5/8" 3306 sx 11399' 9311' Liner 1255' 7' 400 sx 12448' 10261' Liner 632' 5' 136 sx 13000' 10797' Perforation Depth MD(ft): 10632'-12900' Perforation Depth ND(ft): 8692'-10700' 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch E Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Monty Myers Email mmvers(a7hilcorp.com Printed Name Monty Myers Title Drilling Engineer Signatur Phone 777-8431 Date 2/24/2017 _ Commission Use Only Permit to Drill / 3 API Number: Permit Approval See cover letter for other Number: a,I - d oV° 50-- - p`�O41/y-01 -op Date: (0 I requirements. Conditions of approval: If box is checked,well not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: EI ' Other: .1 356E p j-- Coln !e 5 f' Samples req'd: Yes No gj Mud log req'd:Yes❑ No[� 00 • r Lit a.+iL H2S measures: Yes No Directional svy req'd:Yes E 1'No❑ (} Spacing exception req'd: Yes❑ No Inclination-only svy req'd:Yes❑ No Tr 1( KI ...)t 1-INSP c t C� t,. - ,N� A � 1 Por +. '/jebction MIT req'd:Yes❑ No❑ APPROVED BY Approved by0 P COMMISSIONER THE COMMISSION Date:3-G l/ Submit Form Form 10-40 ised 11/2015) Ri f4ltI2 months from the date of approval(20 AAC 5.005(g)) Attachments in Duplicate Hilcorp Alaska, LLC • P.O. Box 244027 Monty Myers Anchorage,AK 99524-4027 Drilling Engineer Tel 907 777 8431 Email mmyers@hilcorp.com Hilcorp Energy Company 2/24/2017 RECEIVED Commissioner FEB 2 4 2017 Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 AOGCC Re: M-28RD Dear Commissioner, Attached is the application for permit to drill M-28RD. I M-28RD is an oil production well planned to be re-drilled in a North-easterly direction from M-28 utilizing the existing casing program down to 8500' MD/7017'TVD. At 8500' MD the parent wellbore will be sidetracked and new wellborg drilled penetrating several Hemlock targets and ultimately penetrating the West Foreland 1 and 2. A 5380' x 8-1/2" open hole section is planned. A 7" 29# L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8" ESP completion. Drilling operations are expected to commence approximately March 24th, 2017. If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. S f ��v Sincerely, G Monty Myers 44,,s r 4"4'1 Drilling Engineer e4426 w �� 90' . 3-z-17 Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC M-28RD Drilling Program McArthur River ro d by: M• tilrMaii Revision 0 February 9, 2017 i • M-28RD Drilling Procedure Rev 0 Iiikorp;iusku.iI.I: Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program 4 4.0 Drill Pipe Information 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 BOP N/U and Test 11 11.0 Mud Program and Density Selection Criteria 12 12.0 Whipstock Running Procedure 13 13.0 Whipstock Setting Procedure 16 14.0 Drill 8-1/2"Hole Section 19 15.0 Run 7"Production Liner 22 16.0 Cement 7"Production Liner 25 17.0 Wellbore Clean Up& Displacement 29 18.0 Run Completion Assembly 30 19.0 RD 30 20.0 BOP Schematic 31 21.0 Wellhead Schematic 32 22.0 Days vs Depth 33 23.0 Geo-Prog 34 24.0 Anticipated Drilling Hazards 35 25.0 FIT Procedure 36 26.0 Choke Manifold Schematic 37 27.0 Offset MW vs.Depth TVD 38 28.0 Casing Design Information 39 29.0 8-1/2"Hole Section MASP 40 30.0 Plot(NAD 27) (Governmental Sections) 41 31.0 Slot Diagram (As Built) (NAD 27) 42 32.0 Directional Program (wp11) 44 • i M-28RD Drilling Procedure Rev 0 !lilt p Uai+ka.11.1: 1.0 Well Summary Well M-28RD Pad& Old Well Designation Sidetrack of existing well M-28(PTD#190-019) Planned Completion Type 7"29#L-80 Liner, 2-7/8"Tubing w/ESP Target Reservoir(s) West Foreland Planned Well TD,MD/TVD 13880' MD/9923' TVD PBTD,MD/TVD 13800' MD/9914' TVD Surface Location(Governmental) 71: FNL, WFWL, Sec 33, T9N,R13W, SM,AK 4<3 Surface Location(NAD 27) X=214174.38, Y=2499500.32 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 1706' FNL, 2227' FWL, Sec 28,T9N, R13W, SM,AK TPH Location(NAD 27) X=215948.38,Y=2504033.25 TPH Location(NAD 83) BHL(Governmental) 1201' FSL, 2276' FEL, Sec 21, T9N, R13W, SM, AK BHL(NAD 27) X=216790.6,Y=2506920.33 BHL(NAD 83) AFE Number 1710804D AFE Drilling Days AFE Drilling Amount $4.1 MM Work String 5" 19.5# S-135 NC-50(Rental string from Weatherford) RKB 160' Water Depth 187' BOP Equipment 13-5/8" 5M Hydril"GK"Annular BOP 13-5/8" 5M Cameron Type U Double Ram 13-5/8" 5M Cameron Type U Single Ram Page 2 Revision 0 February, 2017 • M-28RD Drilling Procedure Rev 0 IIsl ,,rp:I,laxka. 2.0 Management of Change Information Hilcorp Alaska. LLC Hilcorp Emirs"ComPtiq Changes to Approved Permit to Drill Date: February 13, 2017 Subject: Changes to Approved Permit to Drill for M-28RD File#: M-28RD Drilling Program Any modifications to M-28RD Drilling Program will be documented and approved below. Changes to an approved APD will be communicated and approved by the AOGCC prior to continuing forward with work. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared Monty M Myers 02.13 2017 Drilling Engineer Date Page 3 Revision 0 February, 2017 • 0 M-28RD Drilling Procedure Rev 0 Ililcorp.Uacku.1.1.1: 3.0 Tubular Program „) (in) Wt(#/ft) Coupl OD ID(in) Drift(in) Grade Conn Top Bottom 8-1/2" 7" 29 7.656 6.184 6.059 L-80 DWC/C 8300 13880 4.0 Drill Pipe Information Hole OD ID (in) TJ ID TJ Wt Grade Conn Burst Collapse Tension Section (in) (in) OD (#/ft) (psi) (psi) (k-lbs) (in) 8-1/2" 5" 4.276 3-1/4 6-5/8 19.5 S-135 NC-50 17,105 15,638 560 61712. All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 February, 2017 M-28RD Drilling Procedure Rev 0 Ilileurp;Alasku.I.L1: 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. iii. Ensure time entry adds up to 24 hours total. iv. Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates v. Submit a short operations update each work day to pmazzolini(a,hilcorp.com, mmyers@hilcorp.com and cdinger@hilcorp.com 5.3 5am Weekend Update vi. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. vii. Copy pmazzolini@hilcorp.com,and mmyers@hilcorp.com 5.4 EHS Incident Reporting viii. Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times,don't wait until an emergency to have to call around and figure it out!!!! a. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 b. Leonard Dickerson: 0: (907)777-8317 C: (907)252-7855 2. Spills: Keegan F: 0:907-777-8477 C:907-350-9439 ix. Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 x. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally xi. Send final "As-Run"Casing tally to mmyers@hilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cmt report xii. Send casing and cement report for each string of casing to mmyers@hilcorp.com and cdinger@hilcorp.com I Page 5 Revision 0 February, 2017 0 • M-28RD II Drilling Procedure Rev 0 IIiIvor! Uu.ka.1.1,1: 6.0 Planned Wellbore Schematic iii McArthur River Field Well:M-28RD PROPOSED API#:50-733-XXXXX-XX Itileorp Ma.ka., PTD: XXX XXX RKB to Sea Level(MSL)=160' I J I [1, CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 26" 267/397 Dill-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415" Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604" Surf 497' . 9-5/8" 47 N-80 Buttress 8.681" 497' 8,500'(TOW) !4y Vw A h'', ' w" JEWELRY DETAIL '' No Depth(MD) Depth ID Item SOD Liner !„ (TVD) Hanger `: 1 ±8,300' ±6,797' 6.059" SDD Baker Liner Hanger ±8,300' 1 2 ±8,500' ±7,017' - KOP ,. 3 ±8300'-13,880' ±9,814' 6.059" 7"29#L-80 DWC/C 8-1/2" Window 2 ±8,500' 3 CEMENT DETAIL ', No DepthTOC nDDepthTO(TOVolume Item im - 4 ; ,:y ±10,000' ±8,422' 132 bbls 15.3 ppg Class G cement w/'/2 bbl ``� cemnet LCM TO=13,880' PBTD=13,800' Man Hole Angle"83' Page 6 Revision 0 February, 2017 0 0 11 Steel head Platform PROPOSED : 190-019' API: 50-733-20414-00 Hileorp Alaska,LLC Completed:FUTURE 1 2:4' RKB40 TOG Heat tl.4j di ' CASING ANO TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. ._ .1 Ilbisis .---------- 26" 267/397 Dril-Quip Surf 990' 16" 75 K-55 Buttress Surf 1,445' 13-3/8" 61/68 K-55 Buttress 12.415" Surf 4,590' 10-3/4" 51/55 N-80 Buttress 9.604" Surf 497' 9-5/8" 47 N-80 Buttress 8.681" 497' 11,399' ass;teak asra,157 7" 29 N-80 Buttress 6.184" 11,193' 12,448' 5" • 18 N-80 FL4S 4.276" 12,368' 13,000' W I S0,-;it`'� Ttrbk�. CI CIBP*8,500' i :went a .,, 5 Jewelry DetaU 2 Depth Depth 9/2 m non (MD) (TVD) rff 98.8.977' ieeme i :lb,,,, 1 ±8,500' ±7,017' CIBP(Set for whip stock) , !(`iy` -. e' 2 ±9,100' ±7,477' Cement Retainer tS 47' ' '•" *4 ' 3 , Souee¢ediels..pi 1046B Di k �, 3 10,440' 8,541' 8.46 6 Baker 9-5/8"SC-1L .. r . 100x(. ,,,, , �,� � � # 1,....:-) Isolation finer 4 jts and pup.7"29 ,r0:::.,1, _ 4 7 6184 lb/ft L 80 Butt casing with Baker 4 �•,a1''''1*."'';;i. Anchor Assy KBH•22(75x60} ,r *:air" Baker Model FA permanent packer 4! �, 5 10,628' 8,689' 8.437 6 �„r,t gq„ e rim (190FA75)with 6'tieback 5 ' i. ILIF i0,620-106236 10,947' 8,941' 8.25 6.312 Baker 2KP liner packer 7"x 9-5/8" ,.rF ,, 7 7 6.184 Isolation liner 5 jts and pup.7"29 , ,4 * i1i;4.+;4 C-Zone lb/ft Butt L-80 casing t ` + • 8 11,198' 9,144' 7 6.184 Baker Muleshoe Assy.into TIW TBE ,•* +r fit" 9 12,351' 10,170' 5.875 4 Baker FB-1 Packer(Size 85-40) S N 10 12,357' 10,175' 5.156 3.813 Otis X landing nipple °4' ' ,,t ;'; p �� 11 12,369 10,E87' 5.093 4.438 TIW LG-6 Tie back Seals with 14 , �, »-. t muleshoe 11098 +' kA. { cL .,-._.trj `7-- 0 2 A ;4%4. A "Fle►rNodc. ' e r " .7.— Fish/Fill Information: Ate: r., W.ForelandA. 11931'—14.37'Fish(5-7/8"junk mill,bit sub,6-1/16"string mill,x-o) (September 03,1999) B. 11665'—Cleaned out to 11665'w/6"bit on 7/24/14 w : Ft:..r 1 9 a 77:111.r ""`= • • M-28RD Drilling Procedure Rev 0 IIilrorp.Ua-ka.1.1.1: 7.0 Drilling Summary M-28RD is an oil production well planned to be re-drilled in a North-easterly direction from M-28 utilizing the existing casing program down to 8500' MD/7017' TVD. At 8500' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets and ultimately penetrating the West Foreland 1 and 2.1 A 5380' x 8-1/2"open hole section is planned. A 7"29#L-80 DWC/C prod liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 2-7/8"ESP completion. Drilling operations are expected to commence approximately March 24th,2017. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. / A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack -•*4. 317-0 S f and for running the completion assembly General sequence of operations pertaining to this approved drilling procedure: 1. Steelhead Rig 51 will be over slot 3 (M-28) to de-complete and P&A well under separate sundry. et`k 2. DP should be stood back in derrick 3. PU whipstock, and mills and TIH to CIBP 4. Orient whipstock and set at 65 deg right of highside. 5. Mill 8-1/2"window and 35' of new formation at 8500'. 6. POOH and LD mills. PU directional BHA and TIH to window. 7. Swap well to 8.9 ppg oil based drilling mud 8. Perform FIT to 12.5 ppg EMW' 441`1„4/ 9. Drill 8-1/2" production hole from 8535' to 13880' MD, performing short trips as needed f Q 10. Perform short trip and condition mud. POOH 11. LD Directional Tools. RIH w 7" liner. Set liner and cement. Circ wellbore clean. 12. POOH, laying down DP and liner running tools, 13. PU 7" casing scraper assembly and TIH to landing collar. 14. Circ casing clean. POOH laying down DP. 15. Run 2-7/8" completion. (Covered under separate sundry) 16. Land hanger and test. 17. ND BOPE,NU tree and test void Page 7 Revision 0 February, 2017 • • M-28RD Drilling Procedure Rev 0 Ililcorp AIueka,1.1.1. 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2) week intervals during the drilling of M-28RD. Ensure to provide AOGCC 48 hrs notice prior to testing BOPs'' • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min(annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test ALL BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system" • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements" • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: o The calculated MASP for this wellbore when completely evacuated to gas is 3275 psi. However, for Cook Inlet Operations, we assume that the well can never flow 100% gas, due to the water in the reservoir. We reduce this MASP calculation to 2504 psi which assumes that only 2/3 of the wellbore is evacuated to gas and 1/3 to 9.2 ppg reservoir fluid. 41— u 14,0-ectuctig P rtz 7,4 Page 8 Revision 0 February,2017 • • M-28RD Drilling Procedure Rev 0 Ililcorp.Uusku.WV. Hole Section Equipment Test Pressure (psi) • 13-5/8" Hydril GK 5M annular • 13-5/8"5M Cameron U Double gate Initial Test:250/3500 o 2-7/8"X 5"VBR in upr cavity (Annular 2500 psi) o Blind ram in btm cavity 8 1/2" • Mud cross • 13-5/8"5M Cameron U single gate Subsequent Tests: • 3-1/16"5M Choke Manifold 250/3500 • Standpipe,floor valves, etc (Annular 2500 psi) Note: 7"casing ram in lower ram for 8-1/2"hole section. • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back- up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event (BOPs utilized to shut in the well to control influx of formation fluids). • 48 hours notice prior to spud. • 48 hours notice prior to testing BOPs. • 48 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:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz@alaska.gov Victoria Loepp/Petroleum Engineer/(0): 907-793-1247/Email: victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Revision 0 February,2017 • M-28RD Drilling Procedure Rev 0 Ilileorp.Ua.ka.I.1.1: 9.0 R/U and Preparatory Work 9.1 Separate sundries will be submitted that will include the following: • Pull tubing ` • P&A lower perfs with a cement plug # 3 i'7 G ' • Set CIBP 9.2 Mix oil based mud for 8-1/2"hole section. Page 10 Revision 0 February, 2017 • • M-28RD Drilling Procedure Rev 0 IIilrorp.�lu�kn.1.1.1: 10.0 BOP N/U and Test 10.1 * BOPE was NU and tested on prior decompletion sundry. We will test BOPE on 7 day cycle until the window is milled, at that point we will switch to the 14 day test cycle. Continue on to step 11. 10.2 N/U 13-5/8"x 5M BOP as follows (top down): • 13-5/8" x 5M Shaffer annular BOP. • 13-5/8" Shaffer Type "SL" Double ram. (2-7/8" X 5"VBR in top cavity, blind ram in btm cavity) • 13-5/8" mud cross • 13-5/8" Shaffer Type "SL" single ram. (2-7/8"X 5"VBR) • N/U pitcher nipple, install flowline. • Install (2) manual valves on kill side of mud cross. Manual valve used as inside or"master valve". • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 10.3 Run BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! `.47 • Test VBRs on 5"test joint. • Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 10.4 R/D BOP test assy. 10.5 Continue mixing mud for 8-1/2"hole section. 10.6 Set wearbushing in wellhead. Ensure ID of wearbushing> 7". Page 11 Revision 0 February,2017 • • M-28RD Drilling Procedure Rev 0 ililrorp. Iasku.I I( 11.0 Mud Program and Density Selection Criteria 11.1 8-1/2"Production hole mud program summary: Primary weighting material to be used for the hole section will be barite to minimize solids. We will have enough barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. Canrig PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.0 ppg 80/20 Enviromul MOBM Properties: MD Mud Weight Viscosity PV YP HTHP WPS ES (PPM 8,500—13,880' 8.9- 50-80 25-35 15-22 <5 250-270K >580 System Formulation: 80/20 Enviromul MOBM Product f Concentration LVT 0.662 bbl Water .172 bbl INVERMUL NT 4 ppb EZ MUL NT 4 ppb GELTONE V 6-10 ppb Lime 7 ppb DURATONE HT 2 ppb Calcium Chloride 21 ppb BAROID 41 9.2 ppg(as needed) BARACARB 5 3-5 ppb BARABLOK 2 ppb BAROTROL PLUS 4 ppb 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 12 Revision 0 February, 2017 • M-28RD Drilling Procedure Rev 0 Ilileorp:‘Ia+ka, 12.0 Whipstock Running Procedure Section 12.1 through 12.5 is covered under decompletion sundry, drilling proceed to 12.6 12.1 M/U window milling assembly and TIH w/4-1/2" DP out of derrick. • Use a 8-1/2"taper mill and an 8-1/2" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (8500' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the # of joints picked up so we know where we are. 12.3 Pressure test casing to 1500 psi/30 min. Chart record casing test& keep track of the amount of fluid pumped. Stage up to 1500 psi in 500 psi increments. 12.4 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. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH& set in slips. 12.8 Make up float sub, install float. 12.9 Leave assembly hanging in the elevators, and stand back on floor. 12.10 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.11 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 and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 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. 12.12 If needed, open BOP Blinds. Page 13 Revision 0 February,2017 • M-28RD Drilling Procedure Rev 0 Ilileorp.Uusku.1.1A: 12.13 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.14 Release pick up system at this point, Make up mills. 12.15 With the top drive, pick the 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. 12.16 The assembly can now be picked up to ensure that the shear bolt is tight. 12.17 Remove the handling system. 12.18 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP & wear bushing. 12.19 Run in hole at 1 1/2 to 2 minutes per stand. 12.20 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.21 Call for Baker Rep. 15 — 10 stands before getting to bottom. 12.22 Orient at least 30' —45' above the CIBP. Page 14 Revision 0 February, 2017 • •• M-28RD Drilling Procedure Rev 0 Ilikorp Alaska,iii: r1 Window Master G2 Whipstock BAKER I<7.,,,::: 'Pith Torque Master Bottom Trip Anchor HUGHES �`�� 9.625 53.5#Non Special Drift Casing le it Baker Oil Tools • - • Upper Watermelon Mill ■ OD: 8.500 8.500 —* i `. 4— 6.25 Length: 6.25 ) Flex Joint OD: 6.375 . Length: 9.00 W 6.375 —0- ♦— 9.00 Lower Watermelon Mill OD: 8.375 Length: 5.66 Window Mill 40.6 IN OD: _ 8.500 8.250 —► 5.66 Length: 1.13 l Whipstock • OD: 8.000 lim 8.500 �_ Length: 18.54 WAI 1.13 Face Angle: 1.9 ,70, Face Length: 17.08 I Retrieval BTA OD: 8.357 17.08 Length: 3.41 18.54 1.9 Overall length —t Length: 14' WELL INFORMATION CUSTOMER lir FIELD —► =' — 8.000 LEASE I v II WELL NO. SHEAR BOLT 111 I 25,000 3.41 tl '; 35,000 8.357 —* :14— 45,000 55,000 !I I 65,000 75,000 NOTE DIM ENSSONSARBASED ONTECH UNIT DATA.ACTUAL DIMENSIONS MAY VARY Page 15 Revision 0 February, 2017 III • HM-28RD Drilling Procedure Rev 0 nil— .Ua.ka.IAA' 13.0 Whipstock Setting Procedure 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using highside MWD. 13.2 Orient Whipstock to desired direction by turning DP in '/4 round increments. P/U and S/O on DP to work all torque out(Being careful not to set BTA). Whipstock Orientation Diagram: 45 L HS Air 70 R HS MIPY Desired orientation of the Whipstock face is 65 degrees right of high side. Hole Angle at window interval (8500' MD) is 41 deg. The wellbore trajectory is planned to kick off at low and at 21 degrees azimuth. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor 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. (25k shear value). 13.5 P/U 5-10' above top of Whipstock. rk 13.6 Displace to 8.9 ppg 80/20 Enviromul MOBM. it, 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. V 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. / „4";41Page 16 Revision 0 February, 2017 M-28RD intDrilling Procedure Rev 0 Ilil•nrp.Uu+ku.1.1€ 13.10 Estimated metal cuttings volume from cutting window: Wieght of Cuttings For Milled Casing Exit O.D. Of Casing (in) 9.625 I.D. Of Casing (in) 8.535 Whipstock Face Length (Ft) 16.00 Percent of Casing Removed (%) * 38 Milled Area (in^12) 5.908 Volume of Cuttings(inA3) 1134.272 Density of Casing (Ib.lin^3) " 0.283 Weight of Cutting Generated (lbs) 321.0 Calculated Average of Casing Removed Based on Drift Mills (38%) Density of Steel = .283 13.11 Drill approx.35' rat hole to accommodate the rotary drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. 13.12 Circulate Bottoms Up until MW in=MW out. 13.13 Conduct FIT to 12.5 ppg EMW. • (12.5 - 8.9) * 0.052 * 7017' tvd= 1314 psi 13.14 Kick Tolerance • (12.5 - 8.9) * (7017/9924) =2.55 / Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a 2.55 ppg kick tolerance while drilling the interval with a 8.9 ppg fluid density. 13.15 Slug pipe and POOH. Gauge Mills for wear. 13.16 Should a second run be required pick up the following BHA. Page 17 Revision 0 February,2017 0 0 HM-28RD Drilling Procedure Rev 0 I liIcorp.tIa,ka.1.1,1: Back Up Mills Connection Length O.D. WINDOW MILL 4 '/ REG-P X MILL 2.25 8.5 NEW LOWER WATERMELON MILL 4 '/2 REG-P X 4 '/ REG-B 5.5 8.5 FLEX JOINT 4 1/2 REG-P X 4 '/2 REG-B 9.0 6.375 STRING MILL 4 1/2 REG-P X 4 '/2 REG-B 5.5 8.5 FLOAT SUB 4 %2" REG-P X 5 '/" NC50-B 3.0 6.375 30 jts-HWDP 5 1/2" NC50-B X 5 '/" NC50-P 900' 6.5 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 18 Revision 0 February,2017 H0 • M-28RD Drilling Procedure Rev 0 II li•orp Alaska.LLC: 14.0 Drill 8-1/2" Hole Section 14.1 P/U 8-1/2"rotary steerable drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift& caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.51 -0.61 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 450-550 gpm. 14.6 Primary bit will be the Halliburton 8-1/2" MMB PDC bit. Ensure to have a back up bit available on location. COMPONENT DAL Item OD ID Gauge Weight Top Length Cumulative Description Serial Number I (in) (in) (in) ow) Connection (ft) Length (it) ME MMB PDC 6.360 2.750 8.500 88.03 P 4-t!2'REG 0.95 0.95 ® Dingo 7600 Rotary Steerable System 7.625 2 000 144 91 B 4.1.'2"IF 23.16 24.11 - Stabilizer -__ 8 250 _--- ® 6.3 4"DGR(Gamma) 6 760 1 920 97.80 B 4.1 2'IF 8 22 32.33 © Inline Stabilizer(ILS) 6.750 1.920 8.250 112.09 B 4.1 2'IF 2.20 34.53 ® 6-3 4"PWD(Pressure) 6 750 1 920 96 30 B 4-1 2'IF 4 43 38.96 6 6-34"ADR Collar(Resistivity) 6.690 1.920 109 40 B 4.12"IF 24.32 63.28 ® 6-34"DM Collar(Directional) 6 760 3.125 103 40 B 4.1 2'IF 9.16 72.44 in 6-3 4'TM Collar(Mud Pulse 6 770 3.250 103.60 B 4-1.2'IF 10.38 82.82 Teleme 9 6 34"Float Sub 6.810 2 875 102.01 B 4-1 IF 2.99 85.81 10 6 3.4"Non Mag Flex Collar 6.850 2.875 103.47 B 4.1.2'IF 31.09 116.90 1111 6 3 4"Non Mag Flex Collar 6.670 2.938 95 98 B 4.1'2"IF 30 68 147.58 ® 6 3'4"Non Mag Flex Collar 6.590 2.813 95.07 B 4-12"IF 30.78 178.36 ® 4 1'2'IF P x XT-39 8 6.500 2 500 96 36 B 4"XT39 1.51 179.87 ® 6 its 4"XT-39 HWDP 4.000 2.652 24 00 181.40 361.27 ® XT-39 P x 4 12"IF B 6.500 2.875 90 96 B 4.1 2`IF 1.30 362.57 16 6.1 4'Jar 6.500 2.500 88.24 B 4.12"IF 30.00 392.57 ® 4 1 2-IF P x XT-39 B 6 500 2.500 96 36 P 4'XT39 1.62 394.19 ME 9 Its 4'XT-39 HWDP 4.000 2.562 2526 274.50 668.69 Total 668.69 Page 19 Revision 0 February, 2017 •n • M-28RD Drilling Procedure Rev 0 Ilile•orp.tIa+ku.HA: r-] HALLIBURTON211"a'V1C1,12 &� "a 8-1/2" (216mm) MMD75DC PRODUCT SPECIFICATIONS Cutter Type Select Cutter IADC Code M422 ill 4 It Body Type MATRIX i �; Total Cutter Count 72 A Cutter Distribution 13mm 16mm `' itFace 0 46 ♦ *' & Gauge 7 12 te Up Drill 7 0 • '8 4 _ 0 Number of Large Nozzles 0 ' , Number of Medium Nozzles 0 Number of Small Nozzles 7 ' lir ttt Number of Micro Nozzles 0 Number of Ports(Size) 0 4, Number of Replaceable Ports(Size) 0 , - +r Junk Slot Area(sq in) 13.06 = 0 11/4 Normalized Face Volume 37.82% '. API Connection 4-1/2 REG.PIN Recommended Make-Up Torque* 12,461— 17,766 Ft*lbs. Nominal Dimensions** ts Make-Up Face to Nose 10.96 in-278 mm Gauge Length 3 in-76 mm Sleeve Length 0 in-0 mm Shank Diameter 6 in- 152 mm Break Out Plate(Mat.#/Legacy#) 181954/44040 Approximate Shipping Weight 180Lbs.-82Kg. SPECIAL FEATURES Up-Drill Cutters on Gage Pads, 1/16"Stepped Gage,Carbide Impact Arrestor,Optimized Dual Row-"D"Feature Material#846097 *Bit specific recommended make-up torque is a function of the bit I.D.and actual bit sub O.D.utilized as specified in API RP7G Section A.8.2. **Design dimensions are nominal and may vary slightly on manufactured product.Halliburton Drill Bits and Services models are continuously reviewed and refined. Product specifications may change without notice. f)2016 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. www.halliburton.com Page 20 Revision 0 February, 2017 • • M-28RD Drilling Procedure Rev 0 Ilik ur1,.%Iaska.1.I.1: 14.7 TIH to window. Shallow test MWD on trip in. 14.8 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.9 Drill 8-1/2"hole to 13880' MD using rotary steerable assembly. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • See mud program for hole cleaning and LCM strategies. • Ensure solids control equipment is functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss < 6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.10 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.11 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.12 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 February, 2017 • S M-28RD Drilling Procedure Rev 0 Harm p. Iu.ka.1.1.1: C5'' 15.0 Run 7" Production Liner e/ � 15.1 R/U Weatherford 7" casing running equipment. • Ensure 7"DWC/C x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total # of joints before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor& model info. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on &threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • No centralizers to be installed on shoe joint, FC joint, and LC joint. • Install solid body centralizers, one per joint to +/- 10,000' TMD, and leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe & FC. 15.4 Continue running 7"production liner • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 10,000' MD. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 7" DWC/C M/U torques Casing OD Minimum Maximum Yield Torque 7" 19,200 ft-lbs 22,100 ft-lbs 25,000 ft-lbs Page 22 Revision 0 February,2017 • S M-28RD Drilling Procedure Rev 0 .%la+ka.1.1.1: Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Casing 7 in 29.00 lb/ft (0.408 in) L-80 2012 API Spec 5CT Coupling 0 D Material L-80 Grade wit 80.000 Minimum Yield Strength (psi) 1111111110111111111,USA 95.000 Minimum Ultimate Strength (psi) VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Pipe Dimensions Houston. TX 77041 7.000 Nominal Pipe Body O.D. (in) Fax 713-479323400 6.184 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesavam•usa com 0.408 Nominal Wall Thickness (in) 29.00 Nominal Weight (lbs/ft) 28.75 Plain End Weight (lbs/ft) 8.449 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 676.000 Minimum Pipe Body Yield Strength (lbs) 7.030 Minimum Collapse Pressure (psi) 8.160 Minimum Internal Yield Pressure (psi) 7.500 Hydrostatic Test Pressure (psi) Connection Dimensions 7.875 Connection O.D. (in) 6.184 Connection I.D. (in) 6.125 Connection Drift Diameter (in) 4.50 Make-up Loss (in) 1 8.449 Critical Area (sq in) • 100.0 Joint Efficiency (%) ` Connection Performance Properties 676,000 Joint Strength (lbs) 16.650 Reference String Length (ft) 1.4 Design Factor 718.000 API Joint Strength (lbs) 338.000 Compression Rating (lbs) 0 API Collapse Pressure Rating (psi) 8,1 ' API Internal Pressure Resistance (psi) Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 19,200 Minimum Final Torque (ft-lbs) 22,100 Maximum Final Torque (ft-lbs) 25,000 Connection Yield Torque (ft-lbs) Page 23 Revision 0 February, 2017 • • M-28RD 14Drilling Procedure Rev 0 I liIc•orp: Iaska. 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 15.8 Before picking up Baker SDD liner hanger/packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 15.9 M/U Baker SDD 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. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/liner on DP no faster than 1 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. • 15.14 Circulate 1-1/2 drill pipe and liner volume at 9-5/8"window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 February, 2017 ! ! M-28RD Drilling Procedure Rev 0 IliIcorp.Ua,'ku, 16.0 Cement 7" Production Liner • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 15 bbls 12.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Mix and pump 132 bbls of 15.3 ppg class "G" cmt per below recipe with 0.5 lb/bbl of Cemnet or equivalent loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to bring cement up to a minimum of 500' above hemlock in annulus of 7" casing and 8-1/2" open hole. Est TOC 10000' TMD. v 16.6 Displacement fluid will be drilling mud. 352 bbls of displacement fluid 12P' , o r 7 I to d" y3a'� = I 47 Li NL" ,c yT( S C'C N 2 C Cement Calculations 3 /� 1564-5 8-1/2"OH x 7"Liner: (13880' — 10000') x 0.02259 x 1.5 = 132 bbls Shoe Track: 80' x 0.03715 = 3 bbls Total Volume(bbls): 132 + 3 = 135 bbls Total Volume(ft3): 135 bbls x 5.615 ft3/bbl = 758 ft3 Total Volume(sx): 758 ft3 / 1.34 ft3/sk= 566 sx 6 LePage 25 Revision 0 February, 2017 S M-28RD 14Drilling Procedure Rev 0 Ilikmrp.Va.ka.1.I.1: Slurry Information: System Easy BLOK Density 15.3 lb/gal Yield 1.34 ft3/sk :'— Mixed Water 5.879 gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2%BWOC Additives D202 Dispersant 1.5% BWOC D400 Gas Control Agent 0.8% BWOC D154 Extender 8.0%BWOC 16.7 Drop DP dart and displace with drilling mud. 16.8 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point 16.9 If elevated displacement pressures are encountered, position liner at setting depth and cease reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.10 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger(15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.11 Slack off total liner weight plus 30k to confirm hanger is set. 16.12 Do not overdisplace by more than V2 shoe track(-1 bbls). Shoe track volume is 1.8 bbls. 16.13 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 February, 2017 • M-28RD Drilling Procedure Rev 0 I I iIcorp.1111s1sa. 16.14 Bleed pressure to zero to check float equipment. 16.15 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.16 Rotate slowly and slack off 50k downhole to set ZXP. 16.17 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS profile. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area(ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.18 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.19 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 16.20 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.21 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.22 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise)torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.23 NOTE: Some hole conditions may require movement of the drillpipe to "work"the torque down to the setting tool. 16.24 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point,the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 February,2017 • M-28RD Drilling Procedure Rev 0 IIiIcorp.%lu,ka.I.IA: Ensure to report the following on Wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm,note any shutdown during mixing operations with a duration • Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume,whether plug bumped& bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping ofjob. Final circulating pressure • Note if pre flush or cement returns at surface&volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg& cmt report+ "As-Run"liner tally to mm pershilcorp.com Page 28 Revision 0 February,2017 • M-28RD Drilling Procedure Rev 0 Ililvrorp.Uu.ka.1,11: 17.0 Wellbore Clean Up & Displacement 17.1 M/U casing clean out assy complete with casing scraper assys for each size casing in the hole. • 6"bit or mill • Casing scraper& brush for 7"29# casing • +/- 5400' 4"workstring. • Casing scraper& brush for 9-5/8" 47# casing • (2000') 5-1/2" DP • Casing scraper& brush for 9-5/8" 47#casing • 5-1/2" DP to surface. 17.2 TIH & clean out well to landing collar(+/- 13,760' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi-vis sweeps as necessary to carry debris out of wellbore. • Ensure 6"bit is worked down to the landing collar. • Space out the cleanout BHA so that the 6" bit reaches the 7" landing collar when crossover is +/- 30' above the 7" liner top. 17.3 After wellbore has been cleaned out satisfactorily using mud,test casing to 3500 psi/30 min. Ensure to chart record casing test. 17.4 Displace drilling fluid in wellbore with a hi-vis pill followed by filtered inlet water. • Circulate 3 to 4 B/U until clean-up is satisfactory. Do not recirculate fluid, pump and dump • After a couple circulations using FIW, short trip the assy to bring the upper 9-5/8"multi-back assy to surface. • RIH again&tag landing collar w/6" bit. Continue circulation as necessary until fluid cleans up. Make another short trip if necessary. • Pump a chemical train followed by FIW. Target NTU's are 80-100 17.5 TOH w/clean out assy. Page 29 Revision 0 February,2017 S M-28RD Drilling Procedure Rev 0 Ililcorp tlaeku.LLC 18.0 Run Completion Assembly 18.1 Run 2-7/8"tubing completion assembly as per separate Approved Completion Sundry 19.0 RD 19.1 Install BPV in wellhead. RILDs. 19.2 ND BOPE,NU tree, test void 19.3 Prep to skid rig ( 04. &5, f2eel 4.5 r '5 5. /Ye-- "'-'r zt, Page 30 Revision 0 February,2017 • M-28RD Drilling Procedure Rev 0 Ililenrp Alanku, 20.0 BOP Schematic 16" Pipe 1 C' III IIs III 111111 • • 4141. III III lil 111 III Ill III III 3.74' 111 III III Ill Ill Shaffer SI. 2 7/8-5.5 Variables 2.83' 13 5/8 SM Blind 2 1/16 5M manual valves 2 1/16 5M manual and HCR valve ,` �� Ili lulu 111 1.76 IE `/ f li I�Lfi�iii 111 V ;Q:LiI 1111. Shaffer St 13 5 .SM 2 7/8.5.5 Variables 1.44' 1 1 1 ill ill III III Drill deck 13.70' Riser 13 5/8 5M FE X 13 5/8 SM API hub Page 31 Revision 0 February, 2017 H • S M-28RD Drilling Procedure Rev 0 Ilikorp;Uu+ku,1.1A: ► 21.0 Wellhead Schematic Steelhead Platform Tubing hanger,McEvoy SL- M-28 EP-ESP,13 5/8 X 4%IBT lift 26 X 16 X 133/8 X10 3/4 X and susp,w/4"Type H BPV 41/2 profile,2-3/8 continuous control lines BHT3.FMC,B-11-A0, 41/16 SM FE gligvallii e�� Valve,Swab,FMC 120, 10:41/165M FE,HWO,DD ,UM/ 1 . s VA Valve,upper master, CD „.. WKM-M,SSV 41/165M FE, ,(yam , w/18"Omni operator,EE 0'. Valve,wing,FMC-120, 9 41/165M FE,HWO DO ' , 4 (jam,` Valve,Master,FMC-120, - 100 41/16 SM FE,HWO,DO ,b•1, all Ilnill UM ir I�1 a."'" a OI' Tubing head,McEvoy SL-P135/85M ii ii � FE top X 16 X SM FE bottom, ;Liti=; 11! w/2-2 1/16 5M SSO 11: M i7t 1 1. a ■ Tubing head,FMC-TC-60,spec for _ai.' 1�l: ammo in unihead,16 X 5M FE top X 16%SM stdd bottom,w/2-2 1/16 5M 550 II; -tfl'' �i II- Valve,FMC-120, Unihead,FMC Type 2,16 X 5M 21/16 5M FE,HWO AA FE top X 21%2M FMC speedlock bottom,w/4-21/16 5M 550 mr . 3,1•I__ E., III � /.7.� ? ,.. , .....,, .(...„ii ii: , I I Adapter spool,FMC-A-5-S 30"MSS S F 112/11,1, llr�' 1 stdd bottom X 21%2M FMC I speedlock top,w/2-2"LPO p-� - L-_ rmo Starting head,FMC,30"M55 —'—I- J II FE 826'bolt weld I■' I m26 16" 13 3/8" 9 5/8" O 4 1/2 Page 32 Revision 0 February, 2017 • • M-28RD Drilling Procedure Rev 0 IliIr orp.U:ck:. 1.1,1: 22.0 Days vs Depth Days Vs Depth 0 M-28RD 2000 4000 6000 j s 0. 8000 _ v A 10000 - L — 12000 14000 16000 0 5 10 15 20 25 30 35 40 Days Page 33 Revision 0 February, 2017 ini • 0 M-28RD Drilling Procedure Rev 0 Ililrorp t,ln-ka.I.L1: 23.0 Geo-Prog GEOLOGICAL PROGNOSIS • WELL NAME: M-28RD FIELD: MCARTHUR RNER M-28RD SURFACE X: 214174.37 As-Built Survey STATE Alaska SURFACE Y: 2499500.32 �F BOTTOM HOLE X: 216799.26 TVD REF DATUM KB BOTTOM HOLE Y. 2506953.59 TVD REF ELEV 160 Corrected KB based on original well not a fizod elevator COORD REF.SYSTEM NAD27 AK4 True North GROUND ELEV 0.0 PROPOSED TD: 13880 MD WATER DEPTH 187.0 PROPOSED TD: 9924 TVD I I Drill a sidetrack out of the M-28(Steelhead)to test and complete the WF1 thru WF2 benches. Objective: I I I I I I I I I Geo Summary/ Based on subsurface evaluation Justification • M-28RD TARGETS ANTICIPATED FORMATION TOPS&GEOHAZARDS TOP NAME , EXPECTED FLUID MD TVD(FT) I Est.Pressure 1 EMW I Gradient KOP 8500 7,017 3100 8.5 0.44 COAL39 Coal Water 10241 8,658 3400 7.6 0.39 HIX_FW Sand/Conglomerate Oil Sand 10652 9,043 3552 7.6 0.39 COAL59 Coal Water 10694 9,079 3570 7.6 0.39 HTKE-FW Sand/Conglomerate Oil Sand 10702 9,086 3569 7.6 0.39 HK2T Sand/Conglomerate Oil Sand 10747 9,123 3584 7.6 0.39 WF1 Sand/Conglomerate Oil Sand x11858 9,659 4190 8.3 0.43 WF2 Sand/Conglomerate Oil Sand 12349 9,733 4200 8.3 0.43 TD 13880 9,924 4267 8.3 0.43 =Primary Objective = - .n•.ry ••j- is TARGET SIZE 50 FT DATA COLLECTION REQUIREMENTS: Mud Logging 4 man Crew below KOP LWD Data Rotary Steerable, Gamma Res with Triple combo Mad Pass at TD E-Line Lo Data. COMPLETION TYPE ESP Completion ANTICIPATED RATES —500-3000 bpd gross fluid ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE OTHER COMMENTS Well will TD in WF2 zone and will run from 12384MD to 13911 MD in WF2 zone. Page 34 Revision 0 February, 2017 • S M-28RD Drilling Procedure Rev 0 Ililrorp:\laska.1.1,1: 24.0 Anticipated Drilling Hazards Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 35 Revision 0 February,2017 M-28RD Drilling Procedure Rev 0 lilrorp; laxka.I,IC 25.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure.Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 36 Revision 0 February, 2017 H • M-28RD Drilling Procedure Rev 0 Ilikorp U;.,1,.,I.I.1: 26.0 Choke Manifold Schematic TO GAS BUSTER TO DERRICK VENT TO SHALE SHAKERS 4. r T i A 1 b .,. ow ow i w..rT immis .. f I ��'�-, 11 ' • :seilnii4______ WitNMI 4 i ___21.1.1 __________i_ ___._ • mi -- r i 61A A1C+► 1 � ' 0.:211 r 1 I j'.h, CM, -- I 'yii,. 1. 1 ' ., num l r ' �` -' ' It Fr 4111 111 1: 1.41 1 ilea ! •ft1 1 , i__._t „, .01, 41 i . i .2o, i ...1, , . 1 1 I SWAM) CHOKE LINE 1 1 A,�3 SECTION AA * ALL VALVES IN FLOW PATH ARE 3-1/16' 5000 PSI CAMERON GATE TYPE Page 37 Revision 0 February, 2017 • �► M-28RD Drilling Procedure Rev 0 I I ilrorp.V a4ku. 27.0 Offset MW vs. Depth TVD MW vs TVD Offsets 0 -A-15RD2(2002) 1,000 —G-28RD(2000) -G-15RD(1998) 2,000 K-13RD2(2001) 3,000 D-48(1999) M29A(2012, 1700 ft @ 4,000 75 deg) M31B(2013, 1500 ft @ 70 deg) 5,000 0 6,000 7,000 8,000 9,000 I , S 10,000 11,000 - 8.0 9.0 10.0 11.0 12.0 13.0 14.0 15.0 Mud Weight(PPG) Page 38 Revision 0 February, 2017 • • M-28RD Drilling Procedure Rev 0 Ilileorp Alaska.1.1.1 28.0 Casing Design Information Calculation & Casing Design Factors Cook Inlet Offshore DATE: 2/21/2017 WELL: M-28RD FIELD: McArthur River DESIGN BY: Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 2504 psi (See attached MASP determination & calculation) Production Mode MASP: 4748 psi (See attached MASP determination & calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.43 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 7" Top(MD) 8,300 Top (TVD) 6,865 Bottom (MD) 13,880 Bottom (TVD) 9,924 Length 5,580 Weight (ppf) 29 Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 161,820 Tension at Top of Section(lbs) 161,820 Min strength Tension (1000 lbs) 676 Worst Case Safety Factor(Tension) 4.18 Collapse Pressure at bottom (Psi) 3,905 Collapse Resistance w/o tension (Psi) 7,030 Worst Case Safety Factor(Collapse) 1.80 MASP (psi) 2,504 Minimum Yield (psi) 8,160 Worst case safety factor(Burst) 3.26 Page 39 Revision 0 February, 2017 H • 0 M-28RD Drilling Procedure Rev 0 Ililrnrp.uu,ka.1.1,1: 29.0 8-1/2" Hole Section MASP II Maximum Anticipated Surface Pressure Calculation 8-112"Hole Section till= M-28RD Cook Inlet,Alaska MD TVD Planned Top: 8500 7017 Planned TO: 13880 9924 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad COAL39 8,658 3400 Water 7.6 0.39 H1?_FW 9.043 3552 Oil Sand 7.6 0.39 COAL59 9,079 3570 Water 7.6 0.39 HTKE-FW 9,086 3569 Oil Sand 7.6 0.39 HK2T 9,123 3584 Oil Sand 7.6 0.39 WF1 9,659 4190 Oil Sand 8.3 0.43 WF2 9,733 4200 Oil Sand 8.3 0.43 TD 9,924 4267 Oil Sand 8.3 0.43 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date M-31B 9.6-9.7 7,755 9,718 2013 G-28RD 8.6-9.5 8,100 9,600 _ 2000 G-15R0 8.6-9.4 8,500 9,550 1998 M-29A 9.2-9.5 8,050 9,800 2012 4ssumptions: 1. Anticipated fracture gradient at 8500'TMD(7017'TVD)= 0.7= 14.9 ppg EMW 2. Maximum planned mud density for the 8-112"hole section is 9.5 ppg. 3. Calculations assumes 9.2 ppg reservoir contains 213 gas..113 water. Fracture Pressure at window considering a full column of gas from window to surface: 7017(ft)x 0.7(psilft)= 4912 4912(psi)-[0.1(psilft)'7017(ft)]= 4210 psi MASP from pore pressure; normal gradient at TO, (0.43 psiift) 9924(ft)x 0.43(psilft)= 4267 psi 4267(psi)-(0.1(psilfti 9924(f t))= 3275 psi MASP from pore pressure; unknown gas sand at TO_ at 9.2 ppg (0.4784 psiift) 9924(ft)x 0.4784(psilft)= 4748 psi Dow nhole 4748(psi)-[(213r0.1(psilfti9924(ft)]+[(113)'0.4784(psilftr9924(ft)]= 2504 psi Drilling MASP Summary: �l _ -s 9' .400 1. MASP while drilling 8-112"hole is governed by pore pressure minus 213 of wellbore evacuated to gas(remaining 113 remains 9.2 ppg drilling fluid) Page 40 Revision 0 February, 2017 H • II M-28RD Drilling Procedure Rev 0 Ililcorp:Ua.ka.1,IA: 30.0 Plot (NAD 27) (Governmental Sections) i Legend ` ' ` I \ 0 M-28RD_SHL i ADL017594 {., \\\\ \I \Rn X1111 \ \\ � , 1\ ` . t-18 BHL , K.17 8HL \\ X M-28RDTPH I 1 SOO9N013W V • ii 1 / MN 8 I. IPM-28RD_BHL KAMP B K.25PHL I/ 8 Bly''Qj \ • Other Surface Hole Locatron • o\ / \ . • Other Bottom Hole Location , \1 / I o�`\ /?'pp . ..30 8HL "' - Well Paths ` I 1 O 3fF�`[HL TRADING BAY K-30 8HL Q001 and Gas Unit Boundary ,\ // 4.208 •'28 BNL\ Kr/PB 8HL • // , K-09 BHL\ • 8HL 1 i on /// \ • 1 / °III /,/ �. \ TRADING BAY UNIT y3t 8HL ° t i/ • M-31 BHL \\�• T�q / • \ \\ • /• DING BAY UNIT/K-20%g_ BHL \ ---- \ / , \ 0 / 'M \ -- • // _1-1---- 9-/i i�, --------_;_ G-258HL \ / --- / 1 At-31c1%Ht/ A / \ -+ \ 05RD8H4 , , 1• 0 \ \ / 1 0 /./13/K8-12411-BHL \ \ /..-'' •/ \ 0 • \ \ /ir // 1 °° \I-_2$Rl) IPIt \ F- eNk \ \\ ADL017594 '/// _-----. 1-3mfHL \ \ G-058HL / / ..� T� - ! \ •i NNG BAY UNIT G•32 8HL \ }��- /', �,�- ':-CJ BHL /// ^/ p / K4i�D BHL `\ \\\ ///711 /, / :1.29A B%V� /. �./18 BHfM-25 BHL G.180PN BHL G-01 BHL 0' \\ \ ,/ �i // / J"--�j �/v. / -.�-^,'-=-�-01RD BHL K-Y•BH • \ SOO9N013W / J --a" 1 13 /• A• BHL---" \\ Se ' /' / -1 ; I ,h; `S00•NO13W RAtilsIG f' s_ `rs!HL-- \\\ ,\\1 i/1-/-<".:-..:---: 5, "moi------ss. -•err+-',%Rg�-H --/---- ``` __-_- GRLG.ai.,\t i1- .. -':..ter'-- -------I--- 4/1/ tlG-04RD G .... -_--�y , / M•04 BHL /' ` z.•.. Vic• __7.- / 7 - 72BBHL ``'y/)4` ,,' iili ,"��i `4`..\` - ,-•,r 0,, ADL018730.--, ,'' �\\\ / / 11 \\ S. �\w ihN1!). ,i fl- / y� \ G.3.BHL ' i01�BH11 \\ \ .\�\ �\ 1► /, M-698HL ,/ I. /028HV � � `\`\ ., aaZ•s, / //•1.uPye ,' v, 1 1 1 \ J / I I 1 \\ ` \ I\i / .. / ,/' '"� /' G-06R08HL .. / / M.19�i� BHL I\ ♦ \ \ l / `r::• �/ }HL ;-• /// 1 I•'•_I 1•• 0!! 4 \ I d�°` i��1 �i 10134 \• .•M-038HL • rr' /r' /'/ I 1 i 1 \ `\ \ ti}•/,, •// }� G-06 FOIL j' I I 1 `L V \\ \\ 1, /:i•/' ,t'\�'1 \;.y/.' \ �+ f I 1 I /JJ, I I 1 j1 \\\•`\`�\�\\ 1 ",''� �'t'}\OP81@HL/ ADL018730 • i' I I 11 6241eHy `\� (�' M-28RD_SIIL :1 ,\\\ l -' Ste (head In \\S21BHL \ S00'N01 W1---1"----r:-Ti.-. ,b u til ;IA BHL .( r 1'' � I ' y y \r*- + 1 MZ7T1 ,r \ / , I/1 •,1 ` \ , //' ,I f ; 1��'/ I I\\�1 \ ,f -`.\-• ` �\�"" \ G-BARD BHL ' r ,.-'- , 1/'C; l' ‘t"‘ \\ \ , \ .+TtH\DING BAY UNIT M-25 BHL ti .^k(161-'1.--;-11 HL 1 5 / \. I •3Rg2 BHii. L / , • \ • \\ \ / 4'• G-CORD BHL • \ `, ` BML 0 1.000 2.000 II Trading Bay Unit Feet M-28RD Alaska State Plane Zone 4.NAD27 A Ilileorp.AI•.k•,II I Map Date.2/212017 Page 41 Revision 0 February, 2017 III s M-28RD Drilling Procedure Rev 0 IIiIcor)) Ua=ka.1.1.1: 31.0 Slot Diagram (As Built) (NAD 27) 2° 28 SECTION LINE NOT TO SCALE(NTS) 32 33 SECTION CORNER 4C1 i (PROTRACTED) 11 N 2500506 898 E 213854.958' 4,M FNL iN SI CENTER LEG B-1 IA„ ".� I '='s' LAT 60'49 54 939'N ' .'� 538'FWI.INTS) - r-v rn ION.151'36'8 895W 1f .1 N.2499499 259 I ", .•1• E 2 4187 ZONE 4S ASP ZONE 4 NAD 27 Z 1068'FNL(NTS) LEG B-1 1067 FNL(NTS. W J Q 0 U) 0 I— I-. 1136 FNL(NTS) 0 Z W Z J " 0 Z I �P . 0 611'FWL(NTS) • i= 470'FWL NT 0 • LEGA-1 ray 'r.rMa 04 • STEELHEAD PLATFORM • 141,20 LEG B•2 ���) "" N M' . , MrgD M ASBUILT WELL LOCATIONS II, r, SECTION 33 T9N R13W CENTER LEG A-1 CENTER LEG 8-2 LAT 60`49 54.213'N LAT 60'49 54 270'N LON 151.36'8257W LON 151'36'5415'W N 2499427 18T N 2499429534' E 214098.135' E.214239.137' ASP ZONE 4 NAD 27 ASP ZONE 4 NAD 2 7 CENTER LEG A-2 LAT 60'49'53 54414 •�r• LON 151'38'6 777W N.2499357 463' -� 544'FWl(NTS) �• Ir • E 214169.815' • • • ASP ZONE 4 NAD 27 T. • • LEG A-2 NOTES i. BASIS OF HORIZONTAL CONTROL.NAD83 US FEET POSITION (EPOCH 2010)AND VERTICAL CONTROL(NAVD88)IS AN OPUS �•• 111 SOLUTION FROM NGS STATIONS KENS.AC51 AND ANC2 TO . ��OF��-q 112 ESTABLISH CP-1. THE ALASKA STATE PLANE COORDINATES NAD :4' S"�y Zi/ 83 ZONE 4 IN FEET ARE N=2499331 366 -*`i� IN •/ E.1354193 305 � ��: ›alre471A......S ELEV =150 436(NAVD88) __ "'; 2.SECTION LINES SHOWN ARE EXTENSIONS OF PROTRACTED VALUES SCALE /i/ '.-.J.r 3&.'' 3 DATUM TRANSFORMATIONS(NAO8:3 ASPZ4 TO NAD27 ASPZ4) �L—_)1) ` R) //I I %1 1""`�� \WERE DONE USING CORPSCON SOF TWARE VERSION 6.0.1. °"o.ccT HILLCORP ALASKA,LLC • _ a A .s F.4 STEELHEAD PLATFORM WELLS wtt min. *LANG COOK INLET ALASKA DRAWN BV 'CO ill.' AS BUILT SURFACE LOCATION ""` ',SS NAD 27 `"O�","O "" ,..4 f/t4rO,MAPPING 94.11Y11740.MONO BOO,As) r347D Po rO..a.s 501.110, 4/l.1101124.3205.r,w °C"'" PROTRACTED SEC.33 TO9N R13W cuur wcwca•rcr.rrccocw Ilil1 rrrlr 11n.1n,r.r�: 3 SEWARD MERIDIAN,ALASKA Page 42 Revision 0 February, 2017 i M-28RD Drilling Procedure Rev 0 Ilskorp Alaska,LLA: NAD 27 Slot# Well # Northing Easting Latitude Longitude Center Leg 8-1 2499499.259 214167.458 60°49'54.939" -151°36'6.895" 1 M-26 2499505.978 214167.640 60°49'55.006" -151°36'6.894" 2 M-32RD 2499504.406 214171.960 60"49'54.991" -151°36'6.806" 3 M-28 2499500316 214174.375 60°49'54.951" -151°36'6.756" 4 M-27 2499495.577 214173.610 60°49'54.905" -151°36'6.769" 5 Empty 2499492.381 214170.029 60°49'54.872" -151°36'6.839" Leg B-1 6 Empty 2499492.362 214165.235 60°49'54.871" -151°36'6.936" 7 M-29A 2499495.452 214161.556 60°49'54.900" -151°36'7.012" 8 Empty 2499500.052 214160.609 60°49'54.946" -151°36'7.033" 9 M-30 2499504.087 214162.790 60°49'54.986" -151°36'6.991" 10 N/A 2499500.729 214170.099 60°49'54.954" -151°36'6.842" 11 M-25 2499495.774 214167.855 60°49'54.905" -151°36'6.885" 12 M-318 2499500.204 214164.607 60°49'54.948" -151°36'6.952" lCenter Leg 8-2 2499429.534 214239.137 60"49'54.270" -151°36'5.415" 1 M-9 2499429.705 214246.421 60°49'54.274" -151°36'5.268" 2 M-18 2499425.538 214245.127 60°49'54.232" -151°36'5.292" 3 M-2 2499422.705 214240.766 60°49'54.203" -151°36'5.378" 4 M-21 2499423.448 214236.029 60°49'54.210" -151°36'5.474" 5 Empty 2499427.060 214232.883 60°49'54.244" -151°36'5.540" Leg B-2 6 M-6 2499431.832 214232.798 60°49'54.291" -151°36' 5.544" 7 M-7 2499435.552 214235.847 60°49'54.329" -151°36'5.484" 8 M-1 2499436.452 214240.494 60°49'54.339" -151°36' 5.391" 9 M-4 2499433.752 214245.008 60°49'54.313" -151°36'5.298" 10 M-3 2499426.614 214240.677 60°49'54.242" -151°36'5.382" 11 M-5 2499429.508 214236.227 60"49'54.269" -151°36'5.473" 12 Empty 2499432.482 214240.507 60°49'54.300" -151°36'5.388" HILLCORPALASKA.LLC se,sx.. - CA " STEELHEAD PLATFORM WELLS (WE "°vole COOK INLET ALASKA °e"°°B,r ,IB AS BUILT SURFACE LOCATION SCALE 1-97 PROSECT NO +43010 ENCOEMNO:IMPPING I B1P.EYNO I TEYTNO NAD 27 EBOCK NO .:1 PO PO BO%.4 SOLDOTNA M iNete LOCNTK/N ,ttXt ,NlreNO4201 rMr 4•90,42.13:12S•4•90,42.13:12S• PROTRACTED SEC.33 TO9N R13W :SNEIt 3 EMAIL YAWLANEAMUMEC(1COY Ililkorp Alaska,I.I.0 yr 3 SEWARD MERIDIAN.ALASKA Page 43 Revision 0 February, 2017 • • M-28RD Drilling Procedure Rev 0 Ililrorp:11aska.1.1.1: 32.0 Directional Program (wp11) Page 44 Revision 0 February, 2017 • 0 Hilcorp Alaska, LLC Trading Bay Steelhead TBU M-28 Plan: M-28RD Plan: M-28RD WP11 Standard Proposal Report 13 February, 2017 5� Ii aiiiiiimi HALLIBURTON , Sperry Drilling Services • 0 • HALLI B U RTON REFERENCE INFORMATION WELL DETAILS:TBU M-28 H• 1 Coordinate(NUE)Reference:Well TBU M-28,True North Water Depth: 187.00 lICOC�) Vertical(ND)Reference:TBU M-28A Plan a 160.00usft aN/S .E/-W Northing Easting Latittude Longitude Sperry 'l i nc1 Measured Depth Reference:TBU M-28A Plan @ 160.00usft 0.00 0.00 2499500.32 214174.37 60°49'54.951 N 151°39 6.756 W Calculation Method Minimum Curvature Project: Trading Bay HikaryAlaska.LLC .- Site: Site: Steelhead Calculation Method:Minimum Curvature SECTION DETAILS Well: TBU M-28 Error System:ISCWSA Wellbore: Plan: M-28RD Scan Method:Closest Approach 3D Error Surface:Elliptical Conic Sec MD Inc Azi ND +N/-S +E/-W Dleg TFace VSect Target Design: M-28RD WP11 Warning Method:Error Ratio 1 8500.00 40.50 20.95 7017.07 3967.67 1639.56 0.00 0.00 428026 2 8517.00 41.55 18.19 7029.90 3978.18 1643.29 12.30 -60.00 4291.42 3 8567.00 41.55 18.19 7067.32 4009.69 1653.64 0.00 0.00 4324.58 4 9094.05 11.58 350.95 7534.63 4233.67 1701.09 6.00 -169.91 4552.25 DDI = 6.365 5 10276.25 11.58 350.95 8692.79 4467.96 1663.75 0.00 0.00 4763.49 6 11558.29 75.00 10.00 9581.35 5292.63 1761.44 5.00 20.52 5577.92 - 7 11858.29 75.00 10.00 9659.00 5578.01 1811.76 0.00 0.00 5864.86 TBU M-28STwp09 VVFI Tgt - 8 12049.11 82.85 18.50 9695.69 5759.14 1857.95 6.00 47.63 6051.40 - 9 13879.78 82.85 18.50 9923.55 7481.71 2434.31 0.00 0.00 7867.77 TBU M-285T wp09 TD Tgt 6375- - Start Dir 12.3°/100':8500'MD,7017.07'TVD:60°LT TF 6750 -''End Dir:8517'MD,7029.9'ND CASING DETAILS SURVEY PROGRAM 00 - _--' ND MD Name Size Date:2017-01-26T00:00:00 Validated:Yes Version: 91.-_- 9923.55 13879.78 8 112 x 7" 7 Start Dir 6°/100':8567'MD,7067.32'ND Depth From Depth To Survey/Plan Tool 7125 130.00 8500.00 TBU M-28 NSG WL --- 8500.00 13879.78 M-28RD WP11 MWD+SC+sag °,00 End_Dir:9094.05'MD,7534.63'ND 7500 _ - FORMATION TOP DETAILS ' NDPath NDssPath MDPath Formation 8658.00 8498.00 10240.74 COAL39 i904100 8883.00 10652.17 H1X FW , 78758500 9079.00 8919.00 10694.14 COAL59 0 9088.00 8926.00 10702.41 HTKE-FW N 9123.00 8963.00 10746.78 HK2T 9659.00 9499.00 11858.29 WF1 9733.00 9573.00 12348.86 WF2 4.) 8250 Start Dir 5°/100':10276.25'MD,8692.79'ND O 10000 COAL39 ----\---- Fo 8625 _ _ _ - _ - 2 - H1X FW End Dir:11558.29'MD,9581.35'ND 2 _ , - 1py00 \ - ' COAL59 9000-r _ _ Start Dir 6°/100':11858.29'MD,9659'TVD HTKE-FW oo°0 End Dir:12049.11'MD,9695.69'ND 9375- HK2T 4'a" Total Depth:13879.78'MD,9923.55'TVD • - _ _ _ - _ - _ _ _ - _/ N �, _ - _ - _ _ _ _ - _ _ _ _ - _ - _ _ _ _ _ - _ - _ _ J i_ _ _ _ - _ 9750 - WF2 'M-28RD WP11 - TBU M-28ST wp09 WF1 Tgt 'a - 81/2"x7" 10125- M-28 I i i 1 11 111111111IIIIIIIII11111111 4125 4500 4875 5250 5625 8000 6375 8750 7125 7500 7875 8250 8625 9000 9375 9750 10125 10500 10875 11250 Vertical Section at 18.02°(750 usftln) • • Project: Trading Bay WELL DETAILS: ThU M-28 Site: Steelhead Water Depth: 187.00 Well: TBU M-28 +N/-S +E/-W Northing Easting Latittude Longitude Wellbore: Plan: M-28RD 0.00 0.00 2499500.32 214174.37 60°49'54.951 N 151°36'6.756 W Plan: M-28RD WP11 REFERENCE INFORMATION 111 f jl le0('i�) Co-ordinate(N/E)Reference:Well TBU M-28,True North Vertical(TVD)Reference:TBU M-28A Plan @ 160.00usft Measured Depth Reference:TBU M-28A Plan(f/2 160.00ustt Calculation Method:Minimum Curvature 7975- 7700— 8 1/2"x 7" M?8RD 7425— Total Depth:13879.78'MD,9923.55'TVD "991471 7150— 6875— CASING DETAILS TVD TVDSS MD Size Name 6600— 9923.55 9763.55 13879.78 7 8 1/2"x 7" 6325- - M-25 9750 6050— a H _ End Dir:12049.11'MD,9695.69'TVD • 5775— + - _ Start Dir 6°/100':11858.29'MD,9659TVD ° yI • 5500 TBU M-28ST wp09 WFI Tgt ° 5225— End Dir:11558.29'MD,9581.35'TVD 9500 4950- - 9250 4675- - 9000 4400— 8500 End Dir:9094.05'MD,7534.63'TVD 80i° - 7500 4125— Start Dir 6°/100':8567'MD,7067.32'TVD /72s0 End Dir:8517 MD,7029.9'TVD Start Dir 12.3°/100':8500'MD,7017.07TVD:60°LT TF 7000 3850— 6750 3575- - 6500 3300— 613'0 l I I I I I I I I I l I I I I I I I I I I I I I I 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 West(-)/East(+)(550 usft/in) 0 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Coordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Project Trading Bay Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Steelhead Site Position: Northing: 2,499,453.95usft Latitude: 60°49'54.473 N From: Map Easting: 214,083.78 usft Longitude: 151°36'8.560 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.40 ° Well TBU M-28 Well Position +N/-S 0.00 usft Northing: 2,499,500.32 usft Latitude: 60°49'54.951 N +El-W 0.00 usft Easting: 214,174.37 usft Longitude: 151°36'6.756 W Position Uncertainty 0.00 usft Wellhead Elevation: 160.00 usft Water Depth: 187.00 usft Wellbore Plan: M-28RD Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BGGM2016 4/1/2017 16.10 73.72 55,430 Design M-28RD WP11 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,500.00 Vertical Section: Depth From(TVD) +NIS +El-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 18.02 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (") (°) (usft) usft (usft) (usft) (1100usft) (°/100usft) (1100usft) (°) 8,500.00 40.50 20.95 7,017.07 6,857.07 3,967.67 1,639.56 0.00 0.00 0.00 0.00 8,517.00 41.55 18.19 7,029.90 6,869.90 3,978.18 1,643.29 12.30 6.15 -16.06 -60.00 8,567.00 41.55 18.19 7,067.32 6,907.32 4,009.69 1,653.64 0.00 0.00 0.00 0.00 9,094.05 11.58 350.95 7,534.63 7,374.63 4,233.67 1,701.09 6.00 -5.69 -5.17 -169.91 10,276.25 11.58 350.95 8,692.79 8,532.79 4,467.96 1,663.75 0.00 0.00 0.00 0.00 11,558.29 75.00 10.00 9,581.35 9,421.35 5,292.63 1,761.44 5.00 4.95 1.49 20.52 11,858.29 75.00 10.00 9,659.00 9,499.00 5,578.01 1,811.76 0.00 0.00 0.00 0.00 12,049.11 82.85 18.50 9,695.69 9,535.69 5,759.14 1,857.95 6.00 4.11 4.45 47.63 13,879.78 82.85 18.50 9,923.55 9,763.55 7,481.71 2,434.31 0.00 0.00 0.00 0.00 2/13/2017 10:28:36AM Page 2 COMPASS 5000.1 Build 81 • 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -160.00 0.00 0.00 0.00 0.00 -160.00 0.00 0.00 2,499,500.32 214,174.37 0.00 0.00 130.00 0.28 178.53 130.00 -30.00 -0.32 0.01 2,499,500.00 214,174.37 0.22 -0.30 230.00 0.30 160.52 230.00 70.00 -0.81 0.10 2,499,499.50 214,174.46 0.09 -0.74 330.00 0.32 122.83 330.00 170.00 -1.21 0.42 2,499,499.10 214,174.77 0.20 -1.02 430.00 0.62 133.62 429.99 269.99 -1.73 1.05 2,499,498.56 214,175.38 0.31 -1.32 530.00 0.77 98.15 529.99 369.99 -2.20 2.11 2,499,498.06 214,176.43 0.45 -1.44 630.00 1.88 101.98 629.96 469.96 -2.64 4.38 2,499,497.57 214,178.69 1.11 -1.15 730.00 2.20 86.25 729.90 569.90 -2.85 7.90 2,499,497.27 214,182.20 0.64 -0.27 830.00 2.00 80.82 829.83 669.83 -2.45 11.53 2,499,497.59 214,185.85 0.28 1.24 930.00 1.78 74.75 929.77 769.77 -1.76 14.76 2,499,498.20 214,189.08 0.30 2.89 1,030.00 2.67 65.90 1,029.70 869.70 -0.40 18.38 2,499,499.47 214,192.74 0.95 5.31 1,080.00 2.95 58.53 1,079.64 919.64 0.75 20.54 2,499,500.56 214,194.93 0.91 7.07 1,130.00 2.93 42.75 1,129.57 969.57 2.36 22.51 2,499,502.12 214,196.93 1.61 9.20 1,230.00 4.10 20.80 1,229.39 1,069.39 7.58 25.51 2,499,507.27 214,200.06 1.76 15.10 1,280.00 4.97 11.98 1,279.23 1,119.23 11.37 26.59 2,499,511.03 214,201.24 2.23 19.04 1,330.00 7.02 10.52 1,328.95 1,168.95 16.49 27.60 2,499,516.13 214,202.37 4.11 24.22 1,380.00 8.48 9.90 1,378.50 1,218.50 23.13 28.79 2,499,522.73 214,203.72 2.92 30.90 1,430.00 9.52 8.32 1,427.88 1,267.88 30.85 30.03 2,499,530.42 214,205.14 2.14 38.62 1,445.00 9.69 9.64 1,442.67 1,282.67 33.32 30.42 2,499,532.88 214,205.60 1.84 41.10 16" 1,480.00 10.10 12.53 1,477.15 1,317.15 39.22 31.58 2,499,538.75 214,206.90 1.84 47.06 1,530.00 11.33 12.27 1,526.28 1,366.28 48.30 33.57 2,499,547.78 214,209.11 2.46 56.32 1,580.00 13.35 13.48 1,575.12 1,415.12 58.71 35.96 2,499,558.13 214,211.76 4.07 66.96 1,630.00 15.28 15.08 1,623.57 1,463.57 70.69 39.02 2,499,570.03 214,215.11 3.94 79.29 1,680.00 17.20 15.88 1,671.57 1,511.57 84.16 42.76 2,499,583.41 214,219.17 3.87 93.26 1,730.00 18.28 17.52 1,719.19 1,559.19 98.75 47.14 2,499,597.89 214,223.91 2.38 108.49 1,780.00 19.58 19.45 1,766.49 1,606.49 114.13 52.29 2,499,613.13 214,229.44 2.89 124.71 1,830.00 21.60 20.82 1,813.29 1,653.29 130.63 58.35 2,499,629.49 214,235.90 4.15 142.28 1,880.00 22.77 21.70 1,859.59 1,699.59 148.23 65.20 2,499,646.91 214,243.17 2.43 161.13 1,930.00 23.98 21.42 1,905.48 1,745.48 166.68 72.49 2,499,665.17 214,250.91 2.43 180.93 1,980.00 24.53 21.63 1,951.07 1,791.07 185.78 80.03 2,499,684.09 214,258.91 1.11 201.43 2,030.00 25.15 21.88 1,996.44 1,836.44 205.29 87.81 2,499,703.40 214,267.17 1.26 222.39 2,080.00 26.77 20.98 2,041.40 1,881.40 225.67 95.80 2,499,723.57 214,275.66 3.33 244.23 2,130.00 28.90 21.25 2,085.61 1,925.61 247.44 104.22 2,499,745.14 214,284.60 4.27 267.55 2,180.00 30.93 21.93 2,128.94 1,968.94 270.63 113.39 2,499,768.09 214,294.34 4.12 292.43 2,230.00 32.55 22.30 2,171.47 2,011.47 294.99 123.30 2,499,792.21 214,304.84 3.26 318.67 2,280.00 34.13 22.98 2,213.24 2,053.24 320.35 133.88 2,499,817.30 214,316.03 3.25 346.06 2,330.00 35.67 23.35 2,254.24 2,094.24 346.65 145.13 2,499,843.32 214,327.93 3.11 374.55 2,380.00 37.37 23.78 2,294.42 2,134.42 373.92 157.03 2,499,870.29 214,340.49 3.44 404.16 2,430.00 38.70 24.35 2,333.80 2,173.80 402.05 169.60 2,499,898.10 214,353.73 2.75 434.80 2,480.00 39.27 24.92 2,372.67 2,212.67 430.64 182.71 2,499,926.37 214,367.54 1.35 466.04 2,530.00 39.65 24.95 2,411.27 2,251.27 459.46 196.10 2,499,954.85 214,381.64 0.76 497.59 2,630.00 39.77 24.18 2,488.20 2,328.20 517.56 222.66 2,500,012.29 214,409.61 0.51 561.06 2,730.00 39.23 24.73 2,565.36 2,405.36 575.47 249.00 2,500,069.53 214,437.34 0.64 624.27 2,830.00 39.15 24.65 2,642.87 2,482.87 632.88 275.39 2,500,126.28 214,465.13 0.09 687.03 2/13/2017 10:28:36AM Page 3 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (') (°) (usft) usft (usft) (usft) (usft) (usft) 2,638.82 3,030.00 38.37 24.78 2,798.82 2,638.82 746.62 327.74 2,500,238.71 214,520.24 0.39 811.39 3,130.00 38.32 24.97 2,877.25 2,717.25 802.90 353.84 2,500,294.34 214,547.70 0.13 872.99 3,230.00 38.20 24.40 2,955.77 2,795.77 859.17 379.70 2,500,349.95 214,574.93 0.37 934.49 3,330.00 37.85 24.00 3,034.55 2,874.55 915.35 404.95 2,500,405.51 214,601.55 0.43 995.73 3,430.00 37.37 25.92 3,113.77 2,953.77 970.68 430.69 2,500,460.18 214,628.63 1.27 1,056.31 3,530.00 37.27 25.40 3,193.30 3,033.30 1,025.33 456.95 2,500,514.17 214,656.21 0.33 1,116.40 3,630.00 37.17 24.35 3,272.93 3,112.93 1,080.20 482.39 2,500,568.41 214,682.99 0.64 1,176.45 3,730.00 36.97 24.90 3,352.72 3,192.72 1,135.00 507.51 2,500,622.58 214,709.43 0.39 1,236.33 3,830.00 36.83 24.47 3,432.69 3,272.69 1,189.55 532.58 2,500,676.50 214,735.83 0.29 1,295.96 3,930.00 36.53 25.72 3,512.89 3,352.89 1,243.65 557.91 2,500,729.96 214,762.48 0.80 1,355.24 4,030.00 36.43 25.40 3,593.29 3,433.29 1,297.28 583.57 2,500,782.96 214,789.43 0.21 1,414.18 4,130.00 37.30 23.28 3,673.30 3,513.30 1,351.94 608.28 2,500,836.99 214,815.47 1.54 1,473.80 4,230.00 37.90 22.27 3,752.53 3,592.53 1,408.20 631.89 2,500,892.66 214,840.45 0.86 1,534.61 4,330.00 38.73 22.58 3,830.99 3,670.99 1,465.51 655.55 2,500,949.37 214,865.50 0.85 1,596.42 4,430.00 39.55 22.25 3,908.55 3,748.55 1,523.86 679.61 2,501,007.12 214,890.98 0.85 1,659.36 4,530.00 40.02 21.85 3,985.40 3,825.40 1,583.17 703.64 2,501,065.82 214,916.44 0.54 1,723.19 4,590.00 39.95 21.59 4,031.37 3,871.37 1,618.99 717.90 2,501,101.28 214,931.58 0.30 1,761.66 13 3/8" 4,630.00 39.90 21.42 4,062.05 3,902.05 1,642.87 727.31 2,501,124.93 214,941.57 0.30 1,787.29 4,730.00 40.27 22.58 4,138.55 3,978.55 1,702.57 751.44 2,501,184.02 214,967.15 0.83 1,851.52 4,830.00 40.02 20.78 4,215.00 4,055.00 1,762.47 775.26 2,501,243.33 214,992.42 1.19 1,915.86 4,930.00 39.92 21.37 4,291.64 4,131.64 1,822.42 798.35 2501,302.69 215,016.98 0.39 1,980.00 5,030.00 40.18 21.58 4,368.19 4,208.19 1,882.29 821.91 2,501,361.97 215,041.99 0.29 2,044.23 5,130.00 40.00 21.67 4,444.69 4,284.69 1,942.16 845.64 2,501,421.24 215,067.17 0.19 2,108.51 5,230.00 39.75 21.63 4,521.43 4,361.43 2,001.75 869.30 2,501,480.23 215,092.27 0.25 2,172.49 5,330.00 38.85 21.75 4,598.82 4,438.82 2,060.60 892.71 2,501,538.50 215,117.11 0.90 2,235.70 5,430.00 39.18 22.37 4,676.52 4,516.52 2,118.94 916.35 2,501,596.24 215,142.17 0.51 2,298.49 5,530.00 38.37 21.92 4,754.48 4,594.48 2,176.95 939.96 2,501,653.65 215,167.19 0.86 2,360.95 5,630.00 38.68 21.93 4,832.71 4,672.71 2,234.73 963.22 2,501,710.85 215,191.85 0.31 2,423.10 5,730.00 38.23 21.32 4,911.02 4,751.02 2,292.54 986.14 2,501,768.08 215,216.18 0.59 2,485.16 5,830.00 38.62 20.77 4,989.36 4,829.36 2,350.55 1,008.45 2,501,825.52 215,239.90 0.52 2,547.22 5,930.00 39.10 21.23 5,067.23 4,907.23 2,409.12 1,030.94 2,501,883.53 215,263.81 0.56 2,609.88 6,030.00 39.27 20.55 5,144.74 4,984.74 2,468.15 1,053.47 2,501,941.99 215,287.77 0.46 2,672.98 6,130.00 39.55 21.50 5,222.00 5,062.00 2,527.41 1,076.24 2,502,000.68 215,311.99 0.66 2,736.38 6,230.00 39.70 20.77 5,299.03 5,139.03 2,586.89 1,099.24 2,502,059.58 215,336.43 0.49 2,800.06 6,330.00 40.58 20.68 5,375.47 5,215.47 2,647.18 1,122.05 2,502,119.30 215,360.71 0.88 2,864.46 6,430.00 40.18 21.88 5,451.65 5,291.65 2,707.55 1,145.56 2,502,179.08 215,385.68 0.87 2,929.13 6,530.00 39.80 23.40 5,528.27 5,368.27 2,766.86 1,170.29 2,502,237.76 215,411.86 1.05 2,993.19 6,630.00 39.88 22.58 5,605.05 5,445.05 2,825.84 1,195.31 2,502,296.11 215,438.31 0.53 3,057.01 6,730.00 40.30 23.82 5,681.56 5,521.56 2,885.02 1,220.69 2,502,354.66 215,465.12 0.90 3,121.14 6,830.00 40.33 24.15 5,757.81 5,597.81 2,944.14 1,246.99 2,502,413.11 215,492.85 0.22 3,185.49 6,930.00 40.27 25.48 5,834.08 5,674.08 3,002.84 1,274.13 2,502,471.14 215,521.42 0.86 3,249.71 7,030.00 40.70 24.10 5,910.13 5,750.13 3,061.78 1,301.35 2,502,529.39 215,550.07 0.99 3,314.18 7,130.00 41.07 23.12 5,985.74 5,825.74 3,121.76 1,327.56 2,502,588.71 215,577.74 0.74 3,379.33 7,230.00 40.55 19.80 6,061.43 5,901.43 3,182.56 1,351.47 2,502,648.91 215,603.13 2.23 3,444.54 2/13/2017 10:28:36AM Page 4 COMPASS 5000.1 Build 81 • • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/.W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,977.33 7,330.00 40.70 19.15 6,137.33 5,977.33 3,243.94 1,373.18 2,502,709.75 215,626.33 0.45 3,509.63 7,430.00 41.47 20.08 6,212.71 6,052.71 3,305.84 1,395.24 2,502,771.09 215,649.90 0.98 3,575.32 7,530.00 41.50 18.90 6,287.62 6,127.62 3,368.29 1,417.34 2,502,832.98 215,673.51 0.78 3,641.54 7,630.00 41.12 18.03 6,362.74 6,202.74 3,430.90 1,438.25 2,502,895.06 215,695.95 0.69 3,707.55 7,730.00 41.10 19.63 6,438.08 6,278.08 3,493.13 1,459.47 2,502,956.75 215,718.68 1.05 3,773.29 7,830.00 41.28 20.35 6,513.34 6,353.34 3,555.02 1,481.99 2,503,018.07 215,742.70 0.51 3,839.11 7,930.00 41.65 20.03 6,588.27 6,428.27 3,617.16 1,504.84 2,503,079.64 215,767.06 0.43 3,905.27 8,030.00 41.47 21.47 6,663.10 6,503.10 3,679.20 1,528.34 2,503,141.08 215,792.07 0.97 3,971.54 8,130.00 41.85 21.38 6,737.81 6,577.81 3,741.07 1,552.62 2,503,202.35 215,817.85 0.38 4,037.89 8,230.00 41.42 21.15 6,812.55 6,652.55 3,802.99 1,576.72 2,503,263.65 215,843.45 0.46 4,104.22 8,330.00 40.67 20.75 6,887.97 6,727.97 3,864.31 1,600.20 2,503,324.38 215,868.42 0.79 4,169.80 ponn nn 40 50 20.95 7.017.07 6,857.07 3,967.67 1,639.56 2,503,426.75 215,910.29 0.12 4,280.26 t __.-----_________ Start Dir 12.3°/100':8500'MD,7017.0TND:60°LT TF � --- Y a 8,517.00 41.55 18.19 7,029.90 6,869.90 3,978.18 1,643.29 2,503,437.17 215,914.28 12.30 4,291.42 End Dir :8517'MD,7029.9'ND 8,567.00 41.55 18.19 7,067.32 6,907.32 4,009.69 1,653.64 2,503,468.41 215,925.40 0.00 4,324.58 Start Dir 6°/100':8567'MD,7067.32'TVD 8,600.00 39.60 17.64 7,092.38 6,932.38 4,030.11 1,660.25 2,503,488.66 215,932.50 6.00 4,346.04 8,650.00 36.65 16.73 7,131.71 6,971.71 4,059.59 1,669.38 2,503,517.92 215,942.34 6.00 4,376.90 8,700.00 33.71 15.68 7,172.57 7,012.57 4,087.25 1,677.42 2,503,545.37 215,951.06 6.00 4,405.69 8,750.00 30.79 14.45 7,214.86 7,054.86 4,113.01 1,684.37 2,503,570.95 215,958.64 6.00 4,432.34 8,800.00 27.87 12.99 7,258.44 7,098.44 4,136.80 1,690.19 2,503,594.59 215,965.04 6.00 4,456.76 8,850.00 24.98 11.23 7,303.22 7,143.22 4,158.54 1,694.87 2,503,616.21 215,970.25 6.00 4,478.89 8,900.00 22.11 9.04 7,349.05 7,189.05 4,178.19 1,698.41 2,503,635.77 215,974.26 6.00 4,498.67 8,950.00 19.28 6.23 7,395.82 7,235.82 4,195.69 1,700.78 2,503,653.21 215,977.06 6.00 4,516.04 9,000.00 16.50 2.51 7,443.40 7,283.40 4,210.99 1,701.99 2,503,668.48 215,978.64 6.00 4,530.96 9,050.00 13.82 357.37 7,491.66 7,331.66 4,224.05 1,702.02 2,503,681.53 215,979.00 6.00 4,543.40 9,094.05 11.58 350.95 7,534.63 7,374.63 4,233.67 1,701.09 2,503,691.17 215,978.30 6.00 4,552.25 End Dir :9094.05'MD,7534.63'ND 9,100.00 11.58 350.95 7,540.46 7,380.46 4,234.85 1,700.90 2,503,692.35 215,978.14 0.00 4,553.32 9,200.00 11.58 350.95 7,638.43 7,478.43 4,254.67 1,697.74 2,503,712.24 215,975.46 0.00 4,571.18 9,300.00 11.58 350.95 7,736.39 7,576.39 4,274.49 1,694.58 2,503,732.13 215,972.79 0.00 4,589.05 9,400.00 11.58 350.95 7,834.36 7,674.36 4,294.31 1,691.43 2,503,752.02 215,970.12 0.00 4,606.92 9,500.00 11.58 350.95 7,932.32 7,772.32 4,314.12 1,688.27 2,503,771.91 215,967.44 0.00 4,624.79 9,600.00 11.58 350.95 8,030.29 7,870.29 4,333.94 1,685.11 2,503,791.80 215,964.77 0.00 4,642.66 9,700.00 11.58 350.95 8,128.26 7,968.26 4,353.76 1,681.95 2,503,811.68 215,962.10 0.00 4,660.52 9,800.00 11.58 350.95 8,226.22 8,066.22 4,373.57 1,678.79 2,503,831.57 215,959.42 0.00 4,678.39 9,900.00 11.58 350.95 8,324.19 8,164.19 4,393.39 1,675.64 2,503,851.46 215,956.75 0.00 4,696.26 10,000.00 11.58 350.95 8,422.15 8,262.15 4,413.21 1,672.48 2,503,871.35 215,954.08 0.00 4,714.13 10,100.00 11.58 350.95 8,520.12 8,360.12 4,433.03 1,669.32 2,503,891.24 215,951.40 0.00 4,731.99 10,200.00 11.58 350.95 8,618.08 8,458.08 4,452.84 1,666.16 2,503,911.13 215,948.73 0.00 4,749.86 10,240.74 11.58 350.95 8,658.00 8,498.00 4,460.92 1,664.87 2,503,919.23 215,947.64 0.00 4,757.14 COAL39 10,276.25 11.58 350.95 8,692.78 8,532.78 4,467.95 1,663.75 2,503,926.29 215,946.69 0.00 4,763.49 Start Dir 5°/100':10276.25'MD,8692.79'TVD 2/13/2017 10:28:36AM Page 5 COMPASS 5000.1 Build 81 0 0 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (^) (•) (usft) usft (usft) (usft) (usft) (usft) 8,556.00 10,300.00 12.70 352.84 8,716.00 8,556.00 4,472.90 1,663.05 2,503,931.25 215,946.11 5.00 4,767.97 10,400.00 17.50 358.16 8,812.53 8,652.53 4,498.85 1,661.20 2,503,957.24 215,944.89 5.00 4,792.07 10,500.00 22.39 1.23 8,906.50 8,746.50 4,532.94 1,661.13 2,503,991.33 215,945.65 5.00 4,824.48 10,600.00 27.32 3.24 8,997.21 8,837.21 4,574.93 1,662.83 2,504,033.26 215,948.38 5.00 4,864.93 10,652.17 29.90 4.04 9,043.00 8,883.00 4,599.86 1,664.42 2,504,058.14 215,950.58 5.00 4,889.13 H1X_FW 10,694.14 31.98 4.60 9,079.00 8,919.00 4,621.38 1,666.05 2,504,079.62 215,952.74 5.00 4,910.10 COAL59 10,700.00 32.27 4.67 9,083.96 8,923.96 4,624.49 1,666.30 2,504,082.71 215,953.06 5.00 4,913.13 10,702.41 32.39 4.70 9,086.00 8,926.00 4,625.77 1,666.41 2,504,084.00 215,953.20 5.00 4,914.38 HTKE-FW 10,746.78 34.59 5.21 9,123.00 8,963.00 4,650.16 1,668.53 2,504,108.33 215,955.92 5.00 4,938.23 HK2T 10,800.00 37.23 5.76 9,166.10 9,006.10 4,681.23 1,671.52 2,504,139.31 215,959.66 5.00 4,968.70 10,900.00 42.20 6.62 9,242.99 9,082.99 4,744.74 1,678.43 2,504,202.63 215,968.12 5.00 5,031.23 11,000.00 47.18 7.34 9,314.06 9,154.06 4,814.52 1,686.99 2,504,272.19 215,978.39 5.00 5,100.24 11,100.00 52.16 7.94 9,378.76 9,218.76 4,890.05 1,697.14 2,504,347.44 215,990.37 5.00 5,175.20 11,200.00 57.14 8.47 9,436.60 9,276.60 4,970.75 1,708.79 2,504,427.83 216,003.99 5.00 5,255.54 11,300.00 62.12 8.94 9,487.14 9,327.14 5,056.00 1,721.86 2,504,512.74 216,019.13 5.00 5,340.66 11,400.00 67.11 9.38 9,530.00 9,370.00 5,145.17 1,736.24 2,504,601.53 216,035.69 5.00 5,429.90 11,500.00 72.09 9.78 9,564.84 9,404.84 5,237.56 1,751.84 2,504,693.51 216,053.54 5.00 5,522.58 11,558.29 75.00 10.00 9,581.35 9,421.35 5,292.63 1,761.44 2,504,748.33 216,064.48 5.00 5,577.91 End Dir :11558.29'MD,9581.35'TVD 11,600.00 75.00 10.00 9,592.15 9,432.15 5,332.30 1,768.43 2,504,787.82 216,072.44 0.00 5,617.81 11,700.00 75.00 10.00 9,618.03 9,458.03 5,427.43 1,785.20 2,504,882.51 216,091.53 0.00 5,713.46 11,800.00 75.00 10.00 9,643.91 9,483.91 5,522.55 1,801.98 2,504,977.19 216,110.62 0.00 5,809.10 11,858.29 75.00 10.00 9,659.00 9,499.00 5,578.01 1,811.76 2,505,032.39 216,121.75 0.00 5,864.86 Start Dir 0100':11858.29'MD,9659'TVD-WF1 11,900.00 76.69 11.90 9,669.20 9,509.20 5,617.70 1,819.44 2,505,071.89 216,130.40 6.00 5,904.99 11,950.00 78.74 14.14 9,679.83 9,519.83 5,665.30 1,830.45 2,505,119.20 216,142.57 6.00 5,953.65 12,000.00 80.81 16.35 9,688.71 9,528.71 5,712.76 1,843.39 2,505,166.34 216,156.67 6.00 6,002.80 12,049.11 82.85 18.50 9,695.69 9,535.69 5,759.14 1,857.95 2,505,212.34 216,172.35 6.00 6,051.40 End Dir :12049.11'MD,9695.69'TVD 12,100.00 82.85 18.50 9,702.02 9,542.02 5,807.02 1,873.97 2,505,259.82 216,189.54 0.00 6,101.89 12,200.00 82.85 18.50 9,714.47 9,554.47 5,901.12 1,905.46 2,505,353.12 216,223.31 0.00 6,201.11 12,300.00 82.85 18.50 9,726.92 9,566.92 5,995.21 1,936.94 2,505,446.41 216,257.08 0.00 6,300.33 12,348.86 82.85 18.50 9,733.00 9,573.00 6,041.19 1,952.32 2,505,492.00 216,273.58 0.00 6,348.81 WF2 12,400.00 82.85 18.50 9,739.37 9,579.37 6,089.31 1,968.42 2,505,539.71 216,290.85 0.00 6,399.55 12,500.00 82.85 18.50 9,751.81 9,591.81 6,183.40 1,999.91 2,505,633.01 216,324.62 0.00 6,498.77 12,600.00 82.85 18.50 9,764.26 9,604.26 6,277.50 2,031.39 2,505,726.31 216,358.39 0.00 6,597.99 12,700.00 82.85 18.50 9,776.71 9,616.71 6,371.59 2,062.87 2,505,819.61 216,392.17 0.00 6,697.20 12,800.00 82.85 18.50 9,789.15 9,629.15 6,465.69 2,094.36 2,505,912.90 216,425.94 0.00 6,796.42 12,900.00 82.85 18.50 9,801.60 9,641.60 6,559.78 2,125.84 2,506,006.20 216,459.71 0.00 6,895.64 13,000.00 82.85 18.50 9,814.05 9,654.05 6,653.88 2,157.33 2,506,099.50 216,493.48 0.00 6,994.86 2/13/2017 10:28:36AM Page 6 COMPASS 5000.1 Build 81 0 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 9,666.49 13,100.00 82.85 18.50 9,826.49 9,666.49 6,747.97 2,188.81 2,506,192.80 216,527.25 0.00 7,094.08 13,200.00 82.85 18.50 9,838.94 9,678.94 6,842.07 2,220.29 2,506,286.09 216,561.02 0.00 7,193.30 13,300.00 82.85 18.50 9,851.39 9,691.39 6,936.16 2,251.78 2,506,379.39 216,594.79 0.00 7,292.52 13,400.00 82.85 18.50 9,863.83 9,703.83 7,030.26 2,283.26 2,506,472.69 216,628.56 0.00 7,391.74 13,500.00 82.85 18.50 9,876.28 9,716.28 7,124.35 2,314.74 2,506,565.99 216,662.34 0.00 7,490.96 13,600.00 82.85 18.50 9,888.73 9,728.73 7,218.45 2,346.23 2,506,659.28 216,696.11 0.00 7,590.18 13,700.00 82.85 18.50 9,901.17 9,741.17 7,312.54 2,377.71 2,506,752.58 216,729.88 0.00 7,689.39 13,800.00 82.85 18.50 9,913.62 9,753.62 7,406.64 2,409.20 2,506,845.88 216,763.65 0.00 7,788.61 13,879.78 82.85 18.50 9,923.55 9,763.55 7,481.71 2,434.31 2,506,920.31 216,790.59 0.00 7,867.77 Total Depth:13879.78'MD,9923.55'ND-81/2"x 7" Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) TBU M-28ST wp09 WF1 Tgt 0.00 0.00 9,659.00 5,578.01 1,811.76 2,505,032.39 216,121.75 -plan hits target center -Circle(radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 13,879.78 9,923.55 81/2"x7" 7 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Llthology (°) (°) 10,240.74 8,658.00 COAL39 12,348.86 9,733.00 WF2 10,746.78 9,123.00 HK2T 11,858.29 9,659.00 WF1 10,694.14 9,079.00 COAL59 10,702.41 9,086.00 HTKE-FW 10,652.17 9,043.00 H1X_FW 2/13/2017 10:28:36AM Page 7 COMPASS 5000.1 Build 81 0 • Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well TBU M-28 Company: Hilcorp Alaska,LLC TVD Reference: TBU M-28A Plan @ 160.00usft Project: Trading Bay MD Reference: TBU M-28A Plan @ 160.00usft Site: Steelhead North Reference: True Well: TBU M-28 Survey Calculation Method: Minimum Curvature Wellbore: Plan: M-28RD Design: M-28RD WP11 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,500.00 7,017.07 3,967.67 1,639.56 Start Dir 12.3°/100':8500'MD,7017.07'TVD:60°LT TF 8,517.00 7,029.90 3,978.18 1,643.29 End Dir :8517'MD,7029.9'TVD 8,567.00 7,067.32 4,009.69 1,653.64 Start Dir 6°/100':8567'MD,7067.32'TVD 9,094.05 7,534.63 4,233.67 1,701.09 End Dir :9094.05'MD,7534.63'TVD 10,276.25 8,692.78 4,467.95 1,663.75 Start Dir 5°/100':10276.25 MD,8692.79'TVD 11,558.29 9,581.35 5,292.63 1,761.44 End Dir :11558.29'MD,9581.35'TVD 11,858.29 9,659.00 5,578.00 1,811.76 Start Dir 6°/100':11858.29'MD,9659'TVD 12,049.11 9,695.69 5,759.14 1,857.95 End Dir :12049.11'MD,9695.69'TVD 13,879.78 9,923.55 7,481.71 2,434.31 Total Depth:13879.78'MD,9923.55'TVD 2/13/2017 10:28:36AM Page 8 COMPASS 5000.1 Build 81 • • Hilcorp Alaska, LLC Trading Bay Steelhead TBU M-28 Plan: M-28RD M-28RD WP11 Sperry Drilling Services Clearance Summary Anticollision Report 10 February,2017 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Steelhead•TOU M•28•Plan: M-28RD-M-28R13 WP11 Well Coordinates: 2,499,500.32 N,214,174.37 E(60°49'54.95"N,151°36'06.76"W) Datum Height:TBU M-28A Plan(a 160.00usft Scan Range: 8,500.00 to 13,879.78 usft.Measured Depth. Scan Radius Is 1,587.98 usft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build:81 Scan Type: GLOBAL FILTER APPLIED All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 HALLIBURTON ,;, Sperry Drilling Services • IIIII Hilcorp Alaska,LLC HALLIBURTON Trading Bay Anticollision Report for TBU M-28-M-28RD WP11 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:Steelhead-TBU M-28-Plan:M-28RD-M-28RD WP71 Scan Range: 8,500.00 to 13,879.78 usft.Measured Depth. Scan Radius is 1587.98 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 Grayling G-01RD-G-01-0-01 8,500.00 421.24 8,500.00 128.27 8,137.98 1A38 Clearance Factor Pass- G-01RD-G-01 PB1-0-01 PB1 8,500.00 426.92 8,500.00 127.96 8,135.38 1.428 Clearance Factor Pass- G-01RD-G-01 RD-G-01 RD 8,500.00 421.24 8,500.00 128.48 8,137.96 1.439 Clearance Factor Pass- G-25-G-25-G-25 9,125.00 1,074.99 9,125.00 680.07 9,132.29 2.722 Clearance Factor Pass- G-25-G-25-G-25 9,350.00 1,048.15 9,350.00 667.03 9,330.63 2.750 Ellipse Separation Pass- G-25-G-25-G-25 9,640.32 1,035.20 9,640.32 681.82 9,585.02 2,929 Centre Distance Pass- 0-31-G-31-G-31 8,500.00 659.94 8,500.00 179.67 8,123.20 1.374 Clearance Factor Pass- G-32-G-32-G-32 11,017.11 816.58 11,017.11 447.61 10,659.02 2.213 Centre Distance Pass- G-32-G-32-G-32 11,050.00 817.68 11,050.00 447.32 10,670.63 2.208 Ellipse Separation Pass- G-32-G-32-G-32 11,100.00 822.37 11,100.00 449.40 10,696.55 2.205 Clearance Factor Pass- King Salmon K-02-K-02-K-02 13,879.78 1,571.81 13,879.78 1,069.56 11,288.00 3.130 Clearance Factor Pass- K-09-K-09-K-09 12,725.00 393.10 12,725.00 189.27 11,935.87 1.929 Clearance Factor Pass- K-09-K-09-K-09 12,775.00 382.47 12,775.00 185.79 11,912.35 1.945 Ellipse Separation Pass- K-09-K-09-K-09 12,854.13 375.90 12,854.13 195.32 11,875.97 2.082 Centre Distance Pass- K-17-K-17-K-17 13,750.00 1,353.45 13,750.00 560.42 11,885.86 1.707 Clearance Factor Pass- K-17-K-17-K-17 13,879.78 1,302.70 13,879.78 545.56 11,830.39 1.721 Ellipse Separation Pass- K-2 -•- -•' NM= 1111 1111111111111 11111111111111I- - K-21-K-21-K-21 - - - IIIMIIIIIIIII 111.1111111111 - K-21-K-21-K-21 I- - - - - - K-21-K-21RD-K-21RD - K-21-K-21RD-K-21RD - K-21-K-21RD-K-21RD II- - - - - - - K-2 - - 10,425.00 341.87 10,425.00 208.63 12,851.31 2.566 Clearance Factor Pass- K-25(K-16)-K-25-K-25 10,430.63 341.82 10,430.63 208.72 12,852.88 2.568 Centre Distance Pass- K-30-K-30-K-30 13,075.00 1,077.76 13,075.00 593.22 11,984.46 2.224 Clearance Factor Pass- K-30-K-30-K-30 13,225.00 1,033.98 13,225.00 579.19 11,946.63 2.274 Ellipse Separation Pass- 10 February,2017-18.28 Page 2 of 6 COMPASS • • Hilcorp Alaska,LLC HALLIBURTON Trading Bay Anticollision Report for TBU M-28-M-28RD WP11 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design:Steelhead-TBU M-28-Plan: M-28RD-M-28RD WP11 Scan Range: 8,500.00 to 13,879.78 usft.Measured Depth. Scan Radius is 1,587.98 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 K-30-K-30-K-30 13,477.90 1,004.51 13,477.90 621.73 11,882.89 2.624 Centre Distance Pass- K-30-K-30 PB1-K-30 PB1 13,000.00 1,120.41 13,000.00 590.41 11,951.33 2.114 Clearance Factor Pass- K-30-K-30 PB1-K-30 PB1 13,175.00 1,066.85 13,175.00 574.54 11,896.43 2.167 Ellipse Separation Pass- K-30-K-30 PB1-K-30 PB1 13,460.41 1,032.14 13,460.41 627.94 11,802.18 2.554 Centre Distance Pass- Plan:K-24-K-24RD3-K-24RD3 wp02 13,879.78 728.23 13,879.78 611.98 11,970.62 6.264 Clearance Factor Pass- Steelhead TBU M-01-M-01-M-01 8,500.00 1,133.28 8,500.00 1,095.51 7,373.00 30.005 Clearance Factor Pass- TBU M-06-M-06-M-06 13,300.00 1,195.52 13,300.00 1,085.39 12,502.00 10.856 Clearance Factor Pass- TBU M-06-M-06-M-06 13,475.00 1,178.67 13,475.00 1,072.20 12,502.00 11.070 Ellipse Separation Pass- TBU M-06-M-06-M-06 13,501.80 1,178.37 13,501.80 1,072.58 12,502.00 11.139 Centre Distance Pass- TBU M-06-Plan:M-06RD-M-06RD WP03 11,300.00 277.79 11,300.00 131.59 12,205.98 1.900 Clearance Factor Pass- TBU M-06-Plan:M-06RD-M-06RD WP03 11,307.40 277.71 11,307A0 131.89 12,203.82 1.905 Centre Distance Pass- TBU M-12-M-12-M-12 NM= - ll TBU M-12-M-12-M-12 - - TBU M-28-M-28-M-28 8,800.00 25.59 8,800.00 22.83 8,798.16 9.260 Clearance Factor Pass- TBU M-29-M-29A-M-29A 10,782.67 1,185.43 10,782.67 1,076.24 11,720.00 10.857 Ellipse Separation Pass- TBU M-29-M-29A-M-29A 10,800.00 1,185.67 10,800.00 1,076.39 11,720.00 10.850 Clearance Factor Pass- TBU M-29-Plan:M-29RD2-M-29RD2 WP07 11,249.46 549.12 11,249.46 471.45 13,052.67 7.070 Centre Distance Pass- TBU M-29-Plan:M-29RD2-M-29RD2 WP07 11,275.00 550.00 11,275.00 471.04 13,052.67 6.966 Ellipse Separation Pass- TBU M-29-Plan:M-29RD2-M-29RD2 WP07 11,350.00 562.51 11,350.00 480.32 13,052.67 6.844 Clearance Factor Pass- TBU M-30-M-30-M-30 8,500.00 1,239.37 8,500.00 1,129.82 8,410.71 11.313 Centre Distance Pass- TBU M-30-M-30-M-30 13,879.78 1,277.41 13,879.78 1,093.90 13,063.08 6.961 Clearance Factor Pass- TBU M-31-M-31-M-31 10,559.80 263.02 10,559.80 152.08 10,576.65 2.371 Centre Distance Pass- TBU M-31-M-31-M-31 10,575.00 263.27 10,575.00 151.38 10,587.95 2.353 Ellipse Separation Pass- TBU M-31-M-31-M-31 10,600.00 264.70 10,600.00 151.50 10,606.77 2.338 Clearance Factor Pass- TBU M-31-M-31L1-M-31L1 10,429.74 260.82 10,429.74 150.78 10,514.04 2.370 Centre Distance Pass- TBU M-31-M-31L1-M-31L1 10,450.00 261.56 10,450.00 150.66 10,522.58 2.358 Clearance Factor Pass- TBU M-32-M-32-M-32 11,098.65 710.30 11,098.65 638.72 11,877.96 9.924 Centre Distance Pass- TBU M-32-M-32-M-32 11,125.00 710.74 11,125.00 638.55 11,898.40 9.845 Ellipse Separation Pass- 10 February,2017- 18:28 Page 3 of 6 COMPASS • ! Hilcorp Alaska,LLC HALLIBURTON Trading Bay Anticollision Report for TBU M-28 -M-28RD WP11 Closest Approach 3D Proximity Scan on Current Survey Data(North Reference) Reference Design: Steelhead-TBU M-28-Plan: M-28RD-M-28RD WP11 Scan Range: 8,500.00 to 13,879.78 usft.Measured Depth. Scan Radius is 1,587.98 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 TBU M-32-M-32-M-32 11,375.00 754.77 11,375.00 675.24 12,118.57 9.491 Clearance Factor Pass- TBU M-32-M-32 PB2-M-32 P82 10,400.00 1,191.26 10,400.00 1,111.08 10,652.00 14.857 Clearance Factor Pass- TBU M-32-M-32 PB2-M-32 PB2 10,471.73 1,186.86 10,471.73 1,107.29 10,652.00 14.915 Ellipse Separation Pass- TBU M-32-M-32 PB3-M-32 P83 11,098.65 710.30 11,098.65 638.62 11,877.96 9.908 Centre Distance Pass- TBU M-32-M-32 PB3-M-32 PB3 11,125.00 710.74 11,125.00 638.44 11,898.40 9.831 Ellipse Separation Pass- TBU M-32-M-32 PB3-M-32 P83 11,375.00 754.77 11,375.00 675.14 12,118.57 9.478 Clearance Factor Pass- TBU M-32-M-32RD-M-32RD 1.1 11111 - TBU M-32-M-32RD-M-32RD - TBU M-32-M-32RD-M-32RD 1.11 . - - TBU M-32-M-32RD PB1-M-32RD PB1 10,475.00 623.40 10,475.00 541.86 11,111.00 7.645 Clearance Factor Pass- TBU M-32-M-32RD PB1-M-32RD PB1 10,525.00 619.24 10,525.00 538.54 11,111.00 7.673 Ellipse Separation Pass- TBU M-32-M-32RD PB1-M-32RD PB1 10,533.80 619.14 10,533.80 538.63 11,111.00 7.690 Centre Distance Pass- Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 130.00 8,500.00 NSG WL 8,500.00 13,879.78 M-28RD WP11 MWD+SCtsag 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. 10 February,2017- 18:28 Page 4 of 6 COMPASS S • • HALLIBURTON Project: Trading Bay REFERENCE INFORMATION WELL DETAILS:MU M-28 NAD 1927(NADCON CONUS) Alaska Zone 04 Site: Steelhead co-oordinate(WE)Reference:wal TBU M-26.True North Water Depth: 187.00 Well: TBU M-28 Vertical(TVD)Reference:Tau M-260 Plan 43 160°Duan +N/S +p/-W Nortling Pasting Latina& Longitude Sperry Drilling —__ Measured Depth Reference:TBU M-26A Plan a 160.00usfl 0.00 0.00 2499500.32 214174.37 60°49'54.951 N 151°36'6.756W Wellbore: Plan: M-28RD Calculation Method:Minimum Curvature [r Plan. M-28RD WP71 SURVEY PROGRAM GLOBAL FILTER APPLIED:Al wellpaths within 200'+100/1000 of reference I lilcorO8500.00 To 13879.78 Data:2017-01-28x00:00:00 Validated:Yes Version Ladder/S.F. Plots Depth From Depth To Survey/Plan Tool CASING DETAILS 130.00 8500.00 TBU M-28(M-28) NSG WL 8500.00 13879.78 M-28RD WP11 MWD+SGsag TVD TVDSS MD Size Name 9923.55 9763.55 13879.78 7 8 1/2"x 7" I- '2550.00— __ ` I l • -'H \ , / 0 _ QM-32Rq_ I I 120.00 -_ II` 1 19000 __ M•28- F.. 60.00 I / 'Y N I —.. - _I O - N 30.00 I. n _.__.__ '' Z \ \ U - \\\.. i 0.00 r°6 1 i i l l i i 1 1 I 1 1 1 1 ii 11 ) Ill 1111 ill ( ( 1 i Ill 1 1 f I 11 1111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 8525 8800 9075 9350 9825 9900 10175 10450 10725 11000 11275 11550 11825 12100 12375 12650 12925 13200 13475 13750 Measured Depth(550 usft/in) 4.50_ __ Irrillgtr'''. ‘IIW Yr ®®� ti _ i . 3.00— Alik4. ��� At iv, o -Collision Risk Procedures R:1 ��, .1.1.0------ co 0. — 1.50 - 1111k00"14114. - Collision Avoidance Req I 10 No-Go Zone-Stop Drilling 0.00 ii1 ilj11 1 1 11 111 1 1111 ' 1111IIIIIIIII11111111111 1111 1111 1111 1111 1111 1111 8750 9100 9450 9800 10150 10500 10850 11200 11550 11900 12250 12600 12950 13300 13650 14000 14350 Measured Depth(600 usft/in) • • Schwartz, Guy L (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Friday, March 03,2017 7:19 AM To: Schwartz, Guy L(DOA) Subject: RE: M-28RD comments PTD 217-026 We will have Halliburton's real time operations folks watching for interference of the MWD while we are drilling. We will also be monitoring the pressure on the wells that are not P&A'd while drilling. K-21—is P&A'd K-21RD—is shut in M-12—is shut in M-32RD—is shut in Let me know if you have any additional questions. Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, March 02,2017 11:41 AM To: Monty Myers<mmyers@hilcorp.com> Subject: RE: M-28RD comments PTD 217-026 Typo below...wells goes to 82 deg at 12000 ft and (not 13000 ft) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Thursday, March 02,2017 11:33 AM To: mmyers@hilcorp.com Subject: M-28RD comments PTD 217-026 Monty, Looking at the PTD collision summary. There are several wells that fail collision avoidance. How are you going to address these while drilling the well? 1 111 • Also,will require a CBL run on the liner but see that deviation will be pushing 82 deg at end of the well. In this case run Eline log as far as it will drop. Will be able to see the TOC and most of cemented interval. (TOC is planned at 10000 ft and well goes to 82 deg at about 13000 ft md) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Thursday, March 02, 2017 11:33 AM To: mmyers@hilcorp.com Subject: M-28RD comments PTD 217-026 Monty, Looking at the PTD collision summary. There are several wells that fail collision avoidance. How are you going to address these while drilling the well? Also,will require a CBL run on the liner but see that deviation will be pushing 82 deg at end of the well. In this case run Eline log as far as it will drop. Will be able to see the TOC and most of cemented interval. (TOC is planned at 10000 ft and well goes to 82 deg at about,1388tfft md) /4o40 ot Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 1 • • Bettis, Patricia K (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday, February 28, 2017 9:46 AM To: Bettis, Patricia K (DOA) Subject: RE: TBU M-28RD (PTD 217-026): Permit to Drill Application Good morning Patricia, It appears that I used the number provided from our GIS tech, and that is different than what had been previously used. The 10-401 is incorrect. The correct number is 970' FNL, 532' FWL,Section 33,T9N, R13W, SM. Leg B1, slot 3 Steelhead Platform./ The well completion form is correct. ,/ Thank you! Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.govi Sent:Tuesday, February 28, 2017 9:36 AM To: Monty Myers<mmyers@hilcorp.com> Subject:TBU M-28RD (PTD 217-026): Permit to Drill Application Good morning Monty, On Form 10-401, Box 4a, surface location is stated as 1000' FNL, 557 FWL, Section 33,T9N, R13W, SM. On the Well Completion form for TBU M-28, the surface location is given as 970' FNL, 532' FWL, Section 33,T9N, R13W, SM. Leg B1, slot 3 Steelhead Platform. Is the information on the Well Completion form for TBU M-28 correct as to the surface location? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 1 CONFIDENTIALITY NOTICE:This e-mail •age, including any attachments,contains inflation 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, February 28, 2017 9:36 AM To: Monty Myers (mmyers@hilcorp.com) Subject: TBU M-28RD (PTD 217-026): Permit to Drill Application Good morning Monty, On Form 10-401, Box 4a, surface location is stated as 1000' FNL, 557 FWL, Section 33,T9N, R13W,SM. On the Well Completion form for TBU M-28, the surface location is given as 970' FNL, 532' FWL, Section 33,T9N, R13W, SM. Leg B1, slot 3 Steelhead Platform. Is the information on the Well Completion form for TBU M-28 correct as to the surface location? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, February 27, 2017 12:54 PM To: Bettis, Patricia K (DOA) Subject: RE: TBU M-28RD: Permit to Drill Application Thanks Patricia! We made a typo on that.Thanks for letting us know. Do we need to re-submit or will you be able to hand write it in? Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday, February 27, 2017 11:42 AM To: Monty Myers<mmyers@hilcorp.com> Subject:TBU M-28RD: Permit to Drill Application Good morning Monty, M-28RD as proposed will be a redrill of TBU M-28 drilled from the Steelhead Platform. As such,the name of the redrill will be Trading Bay Unit(TBU) M-28RD, not MRF M-28RD. The well name is TBU. MRF is the field acronym. Please advise if Hilcorp is in agreement. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: %a(k. m -25 PTD: /Development Service _Exploratory Stratigraphic Test Non-Conventional FIELD: l►I c..,tfIK P•(AAAA p��/EJ POOL: 1 IG lt/�.7?�G�A /��V „J4 K a 1o.rd.14Ac/ Or/ Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • O El El U, , g =, a a O , a C O cn CC 0 0 CO 0 y. C , oo Cu. O .0 @ �. o �, °t y - , 0 , al o V. °, a c. W' uJ a. 0 3. , , 0• N, a a) rn �' m d co 0; wo- a. o Q N, '' �. : a °v. a O a �, y. 2. N Z. U U) 0, a> , .0 , (a (9. O a m O' (6 U) co W. , _ O V . ,., �. a1 3 • o. 0, N, N,. 2 W O 0aN. ° D a . � O, , , , � W , , , a• i0. E. � .•e >- "o' a, . y0pE. 6. 0 a v1 � � O . o. � . m d , O 8, `EOa, am , , co n. m m c 0 )" 12-' oa 0 '2. y. d c 0 O , o' = Z• N, N• 00• C O, N. y, > 7, N. ._.. 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No special effort has been made to chronologically organize this category of information. TBU M-28RD 50-733-20414-01-00 McArthur River Field Kenai Peninsula Borough, Alaska May 2, 2017 – May 10, 2017 Provided by: Approved by: John Serbeck Compiled by: Allen Odegaard Mike Skiles Joshua Dubowski Distribution Date: June 2, 2017 TBU M-28RD 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................................................................ 2 1.1 Equipment Summary ................................................................................................................. 2 1.2 Crew.......................................................................................................................................... 2 2 GENERAL WELL DETAILS .............................................................................................................. 3 2.1 Well Objectives .......................................................................................................................... 3 2.2 Hole Data .................................................................................................................................. 3 2.3 Daily Activity Summary .............................................................................................................. 4 3 GEOLOGICAL DATA ........................................................................................................................ 6 3.1 Lithostratigraphy ........................................................................................................................ 6 3.2 Lithology Details ........................................................................................................................ 7 3.2.1.1 Tyonek Formation ........................................................................................................... 8 3.2.1.2 Hemlock Formation ....................................................................................................... 13 3.2.1.3 Hemlock H1X_FW ......................................................................................................... 13 3.2.1.4 Hemlock HTKE-FW ....................................................................................................... 14 3.2.1.5 Hemlock HK2T .............................................................................................................. 14 3.2.1.6 Hemlock HK2T_LOWER ............................................................................................... 15 3.2.1.7 Hemlock HK3T .............................................................................................................. 15 3.2.1.8 Hemlock HK4T .............................................................................................................. 16 3.2.1.9 Hemlock HK5T .............................................................................................................. 16 3.2.1.10 Hemlock HK6T .............................................................................................................. 17 3.2.1.11 Hemlock HK7T .............................................................................................................. 17 3.2.1.12 West Foreland Formation .............................................................................................. 19 3.2.1.13 West Foreland H1X_FW ................................................................................................ 19 3.2.1.14 West Foreland WF_2 .................................................................................................... 20 3.2.1.15 West Foreland WF_3 .................................................................................................... 22 3.3 Sampling Program .......................................................................................................................... 23 4 Drilling Data .................................................................................................................................... 24 4.1 Surveys .......................................................................................................................................... 24 4.2 Bit Record ...................................................................................................................................... 35 4.3 Mud Record ............................................................................................................................. 36 5 SHOW REPORTS .......................................................................................................................... 38 6 DAILY REPORTS ........................................................................................................................... 39 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) Final Data CD TBU M-28RD 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Baseline flame ionization total gas & chromatography. 0 hrs. -- Effective Circulating Density (ECD) Haliburton 0 hrs. — Hook Load / Weight on bit RigWatch 0 hrs. — Mud Flow In RigWatch 0 hrs. — Mud Flow Out RigWatch 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & RigWatch) 0 hrs. — Pit Volumes, Pit Gain/Loss RigWatch 0 hrs. — Pump Pressure RigWatch 0 hrs. — Pump stroke counters RigWatch 0 hrs. — Rate of Penetration RigWatch 0 hrs. — RPM RigWatch 0 hrs. — 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Allen Odegaard 19 12 Daniel Fraser 0.5 7 Mike Skiles 11 18 Marquel Mosebay 16 6 Josh Dubowski 9 9 *1 Years’ experience as Logging Geologist *2 Days at wellsite between rig up and rig down of logging unit TBU M-28RD 3 2 GENERAL WELL DETAILS 2.1 Well Objectives M-28RD is an oil production well planned to be re-drilled in a North-easterly direction from the existing M- 28 utilizing the existing casing program down to 8,550’ MD / 7,051’ TVD. At 8,550’ MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock and West Foreland targets. A 5,330’ x 8-1/2” open hole section is planned. A 7” 29# L-80 DWC/C production liner will be run, cemented, and perforated based on data obtained while drilling the interval. The well will be completed with a 3-1/2” ESP completion. The well very closely followed the planned directional path. The kickoff point was 8,550’ MD at 40.4° and began immediately dropping angle to 9.4° by 9,246’ MD. Held inclination at 8°-10° until 10,288’ MD. Continue drilling while building angle to 82° at 11,993’ MD. Held ~82° to 13,636’ (TD). 7” liner was hung from the 9-5/8” casing at 8,300’ MD and ran down to 13,636’ MD. Operator: HILCORP ALASKA, LLC Well Name: TBU M-28RD Field: McArthur River Field County: Kenai Peninsula Borough State: Alaska Company Representatives: Shane Hauck, Evan Harness, Harold Soule, Andy Lundale Location: Surface Coordinates 970' FNL, 532' FWL, Sec 33, T9N, R13W, SM, AK Mud Line Elevation 160’ AMSL Rotary Table Elevation 187’ AMSL Classification: Development - Oil API #: 50-733-20414-01-00 Permit #: 217-026 Rig Name/Type: Steelhead 51 / Steelhead Platform Spud Date May 1, 2017 Total Depth Date: May 10, 2017 Total Depth 13,636’ MD / 9,888.62’ TVD Primary Targets West Foreland Oil Pool Total Depth Formation: West Foreland Completion Status: — LWD-MWD Services. Halliburton / Sperry Drilling Services Directional Drilling Halliburton / Sperry Drilling Services Drilling Fluids Service Halliburton / Baroid Wireline Logging Service — 2.2 Hole Data Hole Section Max Depth TD Formation MW ppg Dev oinc Csg Dia Shoe Depth LOT ppg MD (ft) TVD (ft) MD (ft) TVD (ft) 8 ½” 13,636’ 9,888.62’ WF2 9.15 82.35 7” 13,636’ 9,888.62 N/A TBU M-28RD 4 2.3 Daily Activity Summary May 1, 2017 Rig up & continue working on pre-oil-based mud check list; troubleshoot / resolve SCR issue; run in hole to 8,545'; clean out mud system; pull out of hole form 8,545' to 8,492'; rack back stand & single in to 8,519'; clean pits for oil-based mud. May 2, 2017 Service rig; clean out mud system for oil-based mud; circulate & condition mud; mill window from 8,550' to 8,567'; drill from 8,567' to 8,585'; FIT to 12.68 EMW; drill from 8,585' to 8,606'; circulate & condition hole, begin pulling out of hole. May 3, 2017 Pull out of hole, checking torque on connections; pick up drill pipe; slip & cut drill line; rack back drill pipe; make up bottom hole assembly. May 4, 2017 Make up bottom hole assembly; run in hole to 2,649'; circulate; run in hole from 2,649' to 4,544'; circulate; run in hole from 4,544' to 6,439'; circulate; run in hole from 6,439' to 8,525'; circulate & condition mud; drill from 8,606' to 9,188'. May 5, 2017 Drill from 9,188' to 10,036'; wipe hole to 9,176'; run in hole to bottom; circulate 2 bottoms up (72u Max Gas); drill from 10,036' to 10,560'. May 6, 2017 Drill from 10,560' to 11,272'. May 7, 2017 Drill from 11,272' to 11,296'; circulate & condition hole; pull out of hole. May 8, 2017 Pull out of hole; change out bit; run in hole to bottom with no issues (686u Max gas); drill ahead from 11,296' to 12,130'. May 9, 2017 Drill ahead from 12,130' to 13,261'. May 10, 2017 Drill from 13261' to 13636'—pull out of hole to 9,851' due to pump pressure loss; lay down washed out pipe; run in hole to 12408'; circulate & condition—started packing off—worked torque down to bit; re- established circulation; circulate & condition mud with a mas total gas of 55u, pull out of hole. May 11, 2017 Pull out of the hole, Circulate at window (Max gas 10u), Pull out of the hole and Lay down directional tools and bit, Test BOPs May 12, 2017 Complete testing BOPs, M/U Clean out assembly, RIH to 8515' above window, Circulate and condition mud, Slip and Cut 105' drill line, Continue to RIH, Ream tight spots as needed, Circulate out gas during reaming at 11350'= Max trip gas of 329u at depth. Continue to ream tight spots @ 11670' with a total gas of 205u at depth. Continue to ream from 12500' to bottom at 13636'. Average background gas from tight spot @ 12,500' was 14.3u. Continue to circulate and condition mud at report time. TBU M-28RD 5 May 13, 2017 Continue to circulate and condition mud, "pump sweeps", spot lube pill, POOH from 13636' to 10500', Work through tight spots 12890' to 10600', Trip in Hole, Wash through tight spots at 11500', Max wiper gas of 45u, Note=collected sample at depth, majority of sam ple was sand. Continue to Trip in Hole, circulate and work pipe at 13550' to bottom with a total gas of 36u, Circulate, POOH, Trip pipe out of hole to 8472', break circulation, pump a dry job, Continue to POOH. May 14, 2017 Continue to POOH from 3040’, POOH to surface, R/U Casing tools and equipment, Run 7" Liner to depth, Run hanger tool, Continue to Run Liner on 5" DP, Filling pipe with mud pumps every 10 stands, Continue running 7" Liner on 5" DP at report time. May 15, 2017 Running in the hole 7" Liner on 5" DP, filling pipe with mud pumps every 10 stands, to 11600, circulate out gas, Max Trip Gas = 202units, Continue to run 7" Liner to bottom, working pipe through various tight spots from 11600' to 16336', Circulate and condition stage pumps for cement job. Held PJSM before cementing 7" Liner in place, Completed Cement job of 7" Liner String @ 13636'. TBU M-28RD 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops picked by Hilcorp Geologists FORMATION PROGNOSED ACTUAL MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) KOP 8,500’ 7,017’ -6,830’ 8,550’ 7,052’ -6,892’ Coal-39 10,241’ 8,658’ -8,471’ 10,237’ 8,650’ -8,490’ H1X FW 10,652’ 9,043’ -8,856’ 10,642’ 9,039’ -8,879’ Coal-59 10,964’ 9,079’ -8,892’ 10,689’ 9,082’ -8,922’ HTKE-FW 10,702’ 9,086’ -8,899’ 10,744’ 9,131’ -8,971’ HTK2 10,747’ 9,123’ -8,936’ 10,793’ 9,173’ -9,013’ WF 1 11,858’ 9,659’ -9,472’ 11,799’ 9,637’ -9,477’ WF 2 12,349’ 9,733’ -9,546’ 12,385’ 9,732’ -9,572’ TD 13,880’ 9,924’ -9,737’ 13,636’ 9.887’ -9,727’ TBU M-28RD 7 3.2 Lithology Details Lithology descriptions of all Kenai Group and Mesozoic rock cuttings samples started immediately after drilling out the surface conductor, then continued as per pre-set plans and procedures, and modified when directed by the Hilcorp operations geologist. The Kenai Group of Alaska’s Cook Inlet Basin, which includes the Sterling, Beluga, Tyonek, Hemlock and West Foreland Formations, was deposited by a variable-energy fluvial system within a large closed fore- arc basin. The characteristic sedimentary stratigraphy consists of dominant massive to thinly bedded sandstone and claystone-siltstone, generally abundant thin interbeds of air fall and re-deposited volcanic ash, minor beds of basal or modal conglomerate and extensively-distributed thin beds of coal and carbonaceous rocks. Gradational upward-fining sequences and bi-modal distribution zones are abundant within sandstone sections. Note that in Canrig’s Lithology Descriptions, the special modifying term “tuffaceous” was created to address the pervasive presence and div ersity of soft -sediment volcanogenic- origin rocks in the Cook Inlet area. Though generally applied to significantly ash-rich clay-silt-sand lithologies, its wide use in descriptions may include discernible micro-shard concentrations of disaggregated volcanic glass to vitric air fall volcanic ash to smectite-bentonite clays derived from devitrified ash to rare layers of vitric ignimbrite. TBU M-28RD 8 3.2.1.1 Tyonek Formation The Tyonek formation is a series of alternating tuffaceous sandy siltstones, tuffaceous siltstones, sand and clay with occasional coal and carbonaceous shales. The tuffaceous siltstones are typically medium gray with pale brown and olive hues to medium dark gray with pale olive to very pale brown hues. They are easily friable to friable with a crumbly to pulverulent tenacity and often display bit curled to a rare platy cuttings habit. Typically have a dull to earthy luster with a silty to gritty texture and have a massive structure The sands are typically medium gray to medium gray with pale olive hues to yellowish brown to grayish brown. Grain size is typically lower medium to lower fine to occasionally lower coarse and trace 2-4mm grains. They are typically sub-rounded to rounded to sub-angular with moderate to poor sorting and are sub spherical to trace sub discoidal. The sands are typically comprised of translucent smoky gray to transparent quartz and trace lithics. Ranges from unconsolidated to easily friable to trace amounts of firm clasts. The coals are typically black to very dark gray to occasionally matte black. They display brittle to crumbly to dense tenacity with hackly to conchoidal to irregular fracture. They usually display flakey to an occasional wedge-like cuttings habit. Luster is often vitreous to earthy to slightly waxy with a matte texture. 8,550’ to 10,642' MD (-6,892' to -8,879' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 732 0.4 72.3 1578 3 182 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 8,923 7,365 189 42,423 0 10 9,044 7,479 338 77,489 0 29 3 9,201 7,630 379 84,457 0 21 9,266 7,694 1,033 226,899 0 34 9,306 7,733 229 48,943 0 13 9,419 7,845 232 52,019 0 18 9,500 7,924 277 64,698 0 17 9,603 8,026 370 84,988 0 28 4 9,692 8,114 234 53,769 0 27 9,725 8,146 161 36,551 0 15 9,870 8,289 221 51,376 0 12 9,977 8,395 294 67,714 0 35 5 10,011 8,428 335 76,610 0 27 10,075 8,491 261 61,241 0 14 10,104 8,520 196 45,844 0 13 10,153 8,568 264 60,301 0 17 10,193 8,607 190 43,781 0 14 10,242 8,656 228 51,507 123 27 10,264 8,677 328 72,380 453 355 66 86 18 13 TBU M-28RD 9 Sand / Tuffaceous Siltstone (8550' - 8680') = grayish brown to brownish black to dark olive gray; unconsolidated to very easily friable; upper to lower medium to lower coarse grains, upper fine to upper coarse common; moderate to poor sorting; sub-rounded to sub- angular; sub-spherical to sub-discoidal; translucent to clear to smoky quartz dominated; dark lithics and carbonaceous sediment common; inter- bedded with siltstone/claystone; moderate grayish brown to dusky yellow-brown; poor to moderate induration; irregular to planar fracture; platy to nodular cuttings habit; dull to slight waxy luster; silty to gritty texture; no hydrocarbon indicators present. Tuffaceous Siltstone / Claystone (8680' - 8770') = medium dark gray to brownish gray to grayish black; soft to moderate to semi -poor induration; crumbly to semi -brittle to semi-tough; irregular to earthy to blocky to planar fracture; tabular to platy cuttings habit; dull to waxy luster; silty to gritty texture; unconsolidated very coarse sand to very easily friable sand- stone common; lower medium to upper coarse, occasional upper fine to lower very coarse; poorly to moderately sorted; sub-angular to sub- rounded; sub-spherical to sub-discoidal; quartz dominated; dark lithics common; no hydrocarbon indicators. Carbonaceous Shale (8770' - 8830') = brownish black to brownish gray, grayish black to olive black; moderately hard to occasionally hard; crumbly to slightly brittle tenacity; sub-planar to earthy fractures; sub-wedge-like to sub- platy fractures; dull earthy luster; gritty to silty texture; slight fissil e; non calcareous; petroleum odor masked by oil based mud; no other oil indicators present. Tuffaceous Claystone / Siltstone (8830' - 8900') = overall brownish gray to light to medium olive gray; crumbly to slight crunchy tenacity; irregular to earthy fracture; dominantly sub- planar to common PDC style cuttings; dull earthy luster occasionally sub- waxy; dominantly silty to slightly smooth clayey texture; no visible structure; non calcareous; increasing sandstone; lower fine to upper very fine grains; non calcareous; no petroleum odor or sample fluorescence; no other oil indicators. Coal (8920' - 8930') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally subplaty cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no other oil indicators. Sand / Sandstone (8985' - 9080') = overall medium olive gray to moderate olive brown; light brown, olive gray, milky, light green and occasionally transparent individual grains; quartz framework with scattered lithics; dominantly upper medium to lower fine, scattered coarse to very fine grains; moderate sorting; dominantly very angular to angular, rare sub-rounded grains; low to very low sphericity; sandstone ranging from moderately hard to firm friable; sand has soft clayey matrix with sandstone having calcite cement; petroleum odor masked by oil based mud; sample has overall moderate yellow sample fluorescence; trace free oil on fresh surface and occasional oil stain; fast bright whitish yellow cut streamers with bright yellowish white cut fluorescence; straw to faint brown visual cut; moderately bright yellow residual cut fluorescence; oil indicators may be influenced by LVT. Siltstone / Tuffaceous Claystone (9080' - 9200') = moderate olive brown to light to medium olive gray; moderately hard to moderately soft; irregular to earthy fracture; sub-tabular to common PDC style cuttings; dull earthy luster, occasionally sub-waxy; moderately clayey to silty texture; occasional carbonaceous material in siltstone; petroleum odor masked by oil based mud; even dull yellow sample fluorescence; slow moderately bright yellow cut fluorescence with slow stringers; moderately dark straw to light brown visual cut; oil indicators maybe influenced by oil based mud. Coal (9210' - 8220') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no other oil indicators. TBU M-28RD 10 Sand (9220' - 9340') = overall medium olive gray to moderate olive brown; light brown, olive gray, milky, light green and occasionally transparent individual grains; quartz framework with scattered lithics and rare micas; dominantly lower medium to upper very fine grains, scattered lower coarse; moderate to moderately well sorted; dominantly sub-rounded to sub -angular; low to moderate sphericity; unconsolidated; grain support with occasionally clayey matrix; petroleum odor masked by oil based mud; sample has moderately bright yellow sample fluorescence; trace oil stain; fast bright yellow white cut fluorescence; no streamers; dark straw to light brown visible cut; moderately bright yellow residual cut fluorescence; dark straw to moderate brown residual cut ring; oil indicators maybe influenced by oil based mud. Sandstone (9350' - 9380') = overall light to moderate olive brown to light olive; moderately firm to firm friable, friable; quartz framework with scattered feldspar and calcite, occasional dark lithics; dominantly lower medium to lower fine; moderate to fair sorting; sub-angular to sub-rounded; low to moderate sphericity; grain support with rare calcite cement; occasional carbonaceous material; weak reaction to HCl; even dull yellow sample fluorescence; petroleum odor masked by oil based mud. Sand (9390' - 9500') = overall light to medium olive brown to medium olive gray; upper medium to lower fine grains; quartz framework with scattered lithics; fair to moderately well sorted; sub-angular to sub- rounded; low to moderate sphericity; unconsolidated; grain support with occasional clayey matrix; scattered carbonaceous material; petroleum odor masked by oil based mud; even moderately dull yellow sample fluorescence; moderate yellow cut fluorescence; medium straw visible cut; light straw residual cut ring; dull yellow residual cut fluorescence; oil indicators maybe influenced by oil based mud. Coal (9500' - 9540') = dominantly black to brownish black; tough to brittle tenacity, occasionally slightly crumbly; irregular, splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; greasy to waxy luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no oil indicators. Sand (9540' - 9610') = overall light to medium olive brown to medium olive gray; upper medium to lower fine grained; quartz framework with scattered lithics; fair to moderately well sorted; sub-angular to sub- rounded; low to moderate sphericity; unconsolidated; predominantly grain supported with occasional clayey matrix; scattered carbonaceous material; oil based mud masks and hydrocarbon indicators. Sand (9610' - 9690') = grayish black to dark yellowish brown; predominantly unconsolidated to trace easily friable; lower coarse to upper fine; trace very coarse to very fine grains; minor 2-3mm quartz grains; bit broken quartz grains common; poor to moderate sorting; sub-angular to angular to sub-rounded to rounded; sub-spherical to sub-discoidal; predominantly clear to translucent quartz with minor dark lithics; minor matrix supported tuffaceous sand- stone; carbonaceous sediment common; minor siltstones; claystones rare; no hydrocarbon indicators observed. Tuffaceous Claystone / Carbonaceous Shale (9690' - 9760') = very dark gray to black to brownish black as low rank coal to brownish black to brownish gray as fine disseminated carbonaceous material inter-bedded in shale; shale grades to and inter-bedded with a less indurated carbonaceous claystone/ siltstone; thin coal seams in all lithologic types; moderate to low density; crumbly to firm friable; tabular to nodular cuttings with blunt edges; PDC bit buttercurl cuttings common; dull luster; matte texture; non- calcareous. Tuffaceous Sandstone / Tuffaceous Siltstone (9760' - 9850') = dark yellow- brown to grayish black; firm friable to easily friable to unconsolidated; lower coarse to upper fine grained; trace very coarse to very fine grains; trace 2-3mm quartz grains; poor sorting; sub-angular to sub-rounded to rounded; sub- spherical to sub-discoidal; trace bit broken grains; typically matrix supported with common grain supported; tuffaceous matrix; non calcareous; carbonaceous sediment and dark lithics are common; siltstones common; claystones common; no visible hydrocarbon indicators observed. TBU M-28RD 11 Coal (9850' - 9900') = matte black to grayish black to very dark brownish black; tough to brittle tenacity; occasionally slightly crumbly; irregular to splintery, hackly fracture; dominantly sub-wedge-like to occasionally sub-platy cuttings habit; waxy to matte luster; abrasive texture; dominantly sub-bituminous; no petroleum odor or sample fluorescence; no oil indicators. Tuffaceous Sandstone (9900' - 10000') = pale yellow-orange to pale yellow brown with some dusky yellow to light olive brown; friable to easily friable to unconsolidated; lower coarse to very fine grained, trace to common very coarse to 2-3mm quartz grains; poorly sorted; round to sub-rounded to sub-angular to angular; sub-spherical to sub-discoidal; individual grains trans- parent to translucent, polished to frosted surface abrasion; predominantly matrix supported with some grain supported; tuffaceous matrix; non-calcareous; carbonaceous sediment and dark lithics are common; inter-bedded with siltstone; also occasionally inter-bedded with claystones; often inter-bedded with coal seams; no hydrocarbon indicators. Tuffaceous Sandstone / Tuffaceous Siltstone (10010' - 10100') = dark yellow brown to grayish black; firm friable to easily friable to unconsolidated; lower coarse to upper fine grained; trace very coarse to very fine grains; trace 2-3mm quartz grains; poor sorting; sub-angular to sub-rounded to rounded; sub- spherical to sub-discoidal; trace bit broken grains; typically matrix supported with common grain supported; tuffaceous matrix; non calcareous; carbonaceous sediment and dark lithics are common; siltstones common; claystones common; no visible hydrocarbon indicators observed. Sandstone (10100' - 10180') = overall medium olive gray to light olive brown; upper medium to lower fine grains; dominant quartz framework with scattered feldspar, calcite and dark lithics; moderate to fair sorting; dominantly sub-rounded to sub-angular common angular and rounded grains; low to moderate sphericity; dominantly grain support with rare calcite cement; rare carbonaceous material and micas; petroleum odor masked by oil based mud; even moderate dull yellow sample fluorescence; moderately dull yellow cut fluorescence; light brown visible cut; mod dull yellow residual cut fluorescence; faint straw residual cut ring; oil indicators maybe influenced by oil based mud. Carbonaceous Shale (10190' - 10260') = dark yellowish brown to dark olive gray, brownish black; moderately hard to hard; tough, slightly brittle tenacity, occasionally brittle; sub-planar earthy fracture; dominantly sub-wedge-like to sub-platy cuttings habit; dull earthy luster occasionally sub-greasy to sub waxy; gritty to slightly silty texture; non calcareous; petroleum odor masked by oil based mud; spotty dull yellow sample fluorescence; weak yellow cut fluorescence; oil indicators maybe influenced by oil based mud. Note: Coal 39 was from 10,237’ to 10,254' MD (-8,490' to -8,507' TVDSS) Sand (10260' - 10340') = overall light to medium olive gray to light olive brown; light brown, light olive gray, light green, milky and occasionally transparent individual grains; lower coarse to upper fine grains; sub-rounded to sub-angular, occasionally angular; low to moderate sphericity; moderately poor to fair sorting; dominant quartz framework with scattered dark lithics and trace micas; unconsolidated; grain support with occasional clayey matrix; trace carbonaceous material; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; slow rare oil stain; weak slow yellow streamers; faint yellow cut fluorescence; faint straw visible cut; faint brown residual cut ring; moderate yellow residual cut stain; oil indicators may be influenced by oil based mud. Sandstone (10370' - 10460') = overall light to medium olive gray to light olive brown; dominantly upper fine to upper medium, scattered upper very fine grains; dominant quartz framework with occasional feldspar and dark lithics; moderately poor to fair sorting; dominantly sub-rounded to sub-angular common angular and rounded grains; low to moderate sphericity; dominantly grain support with rare calcite cement; rare carbonaceous material and micas; dominantly non calcareous; petroleum odor masked by oil based mud; TBU M-28RD 12 Coal (10460' - 10510') = grayish black to brownish black, olive black, black; moderately hard to hard; tough occasionally slightly brittle tenacity; irregular to sub-planar fracture occasionally blocky, sub- conchoidal; sub-platy to wedge-like cutting habit; sub-flaky to scattered sub-bladed; overall sub-greasy to sub-earthy luster; matte to abrasive texture; ranging from dominantly subbituminous to bituminous; non calcareous; oil indicators masked by oil based mud. Sand (10540' - 10650') = overall light to medium olive gray to light olive brown, light to medium brown; light brown, transparent, milky, olive gray and occasionally light green individual grains; lower coarse to lower medium, scattered finer and coarser grains; dominantly sub-angular to angular, occasionally sub- rounded; moderate to low sphericity; moderate to fair sorting; dominant quartz framework with scattered feldspar and dark lithics, occasional calcite; unconsolidated with rare clayey matrix; petroleum odor masked by LVT; even bright yellow sample fluorescence; fast bright whitish yellow cut fluorescence with faint yellow streamers; medium straw to light brown visible cut; moderately bright yellow residual cut fluorescence; light brown residual cut ring; oil indicators may be influenced by oil based mud. TBU M-28RD 13 3.2.1.2 Hemlock Formation The Hemlock formation is comprised mainly of conglomeratic and tuffaceous sandstone with occasional tuffaceous siltstones and trace coal beds. The tuffaceous sandstones are often medium gray to medium dark gray with a slight light olive gray to olive gray. Grain size is typically lower fine to upper fine with occasional coarse grading to lower medium to upper medium and occasional coarse grained. Often spherical to sub discoidal with sub rounded to rounded, rare sub angular grains. Typically well to moderately well sorted and often friable or unconsolidated. Overall the clasts have a tuffaceous matrix and are grain supported. They appear to be texturally sub mature to immature and dominated by translucent or transparent quartz with pitted or etched facies. Mafic and green lithics are also semi common. The conglomeratic sands observed are typically medium dark gray to medium gray with pale olive to moderate brown to black secondary hues. They are unconsolidated to easily friable with lower medium to upper fine grains and 3-5mm bit broken quartz grains being semi common. Often display poor to moderate sorting, sub angular to sub rounded to angular with sub spherical to trace sub discoidal sphericity. The tuffaceous siltstones can often grade to a sandy siltstone and are typically poorly indurated. Overall tenacity ranges from crumbly to brittle with an irregular to earthy fracture. Cuttings are commonly “bit stacked to slightly tabular with a dull to earthy luster and a silty to gritty texture. Carbonaceous banding is common but not abundant. 3.2.1.3 Hemlock H1X_FW 10,642’ to 10,695' MD (-8,879' to -8,928' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 184.04 18.30 107.90 31.21 6.24 13.62 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Sandstone / Siltstone (10650' - 10760') = dusky to dark yellow-brown to grayish black to olive gray; unconsolidated to easily friable to firm friable; predominantly upper fine to lower coarse, upper coarse to lower fine common; poor to moderate sorting; sub- rounded to sub-angular; sub-spherical to sub- discoidal; trace bit broken grains; translucent to clear quartz dominated; carbonaceous sediment common; siltstones are typically dark grayish black to olive black; poor induration; semi-tough to brittle and crumbly; blocky to irregular to earthy fracture; platy to tabular cuttings habit with PDC bit buttercurl cuttings in the higher clay content clasts; gritty to granular texture; no visible hydrocarbon indicators observed over oil based mud. Note: Coal 59 was from 10,689’ to 10,696' MD (-8,922' to -8,929' TVDSS) TBU M-28RD 14 3.2.1.4 Hemlock HTKE-FW 10,695’ to 10,744' MD (-8,928' to -8,971' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 136.69 3.7 96.37 94.57 5.93 18.67 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 10,740 9,127 91.76 15,687 1,387 742 99 185 37 37 Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone / Siltstone 10900' - 11040') = dusky yellowish brown to grayish black to moderate brown hues to olive gray; unconsolidated to firm friable; predominantly upper coarse to lower fine grained; very common 2-3mm grains; very poorly to poorly sorted; sub-angular to sub-rounded; sub- spherical to sub-discoidal; trace bit broken grains; translucent to clear, quartz dominated; carbonaceous sediment common; siltstones are typically dark grayish black to olive black; poor induration; semi -tough to brittle, crumbly; blocky to irregular to earthy fracture; platy to tabular cuttings habit with PDC bit buttercurl cuttings in the higher clay content clasts; gritty to granular texture; minor claystone throughout; petroleum odor masked by LVT oil based mud; even bright yellow sample fluorescence; fast bright white-yellow cut fluorescence with faint yellow streamers; medium straw-light brown visible cut; moderately bright yellow residual cut fluorescence; light brown residual cut ring; hydrocarbon indicators may be influenced by oil based mud. 3.2.1.5 Hemlock HK2T 10,744’ to 10,793' MD (-8,971' to -9,013' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 109.21 25.91 80.53 50.56 26.21 35.11 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone / Siltstone 10900' - 11040') = dusky yellowish brown to grayish black to moderate brown hues to olive gray; unconsolidated to firm friable; predominantly upper coarse to lower fine grained; very common 2-3mm grains; very poorly to poorly sorted; sub-angular to sub-rounded; sub- spherical to sub-discoidal; trace bit broken grains; translucent to clear, quartz dominated; carbonaceous sediment common; siltstones are typically dark grayish black to olive black; poor induration; semi -tough to brittle, crumbly; blocky to irregular to earthy fracture; platy to tabular cuttings habit with PDC bit buttercurl cuttings in the higher clay content clasts; gritty to granular texture; minor claystone throughout; petroleum odor masked by LVT oil based mud; even bright yellow sample fluorescence; fast bright white-yellow cut fluorescence with faint yellow streamers; medium straw-light brown visible cut; moderately bright yellow residual cut fluorescence; light brown residual cut ring; hydrocarbon indicators may be influenced by oil based mud. TBU M-28RD 15 3.2.1.6 Hemlock HK2T_LOWER 10,793’ to 10,893' MD (-9,013' to -9,095' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 151.59 5.68 85.30 143.88 14.98 56.71 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 10,811 9,188.5 143.88 24,549 2,082 1172 150 294 60 57 Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone / Siltstone 10900' - 11040') = dusky yellowish brown to grayish black to moderate brown hues to olive gray; unconsolidated to firm friable; predominantly upper coarse to lower fine grained; very common 2-3mm grains; very poorly to poorly sorted; sub-angular to sub-rounded; sub- spherical to sub-discoidal; trace bit broken grains; translucent to clear, quartz dominated; carbonaceous sediment common; siltstones are typically dark grayish black to olive black; poor induration; semi -tough to brittle, crumbly; blocky to irregular to earthy fracture; platy to tabular cuttings habit with PDC bit buttercurl cuttings in the higher clay content clasts; gritty to granular texture; minor claystone throughout; petroleum odor masked by LVT oil based mud; even bright yellow sample fluorescence; fast bright white-yellow cut fluorescence with faint yellow streamers; medium straw-light brown visible cut; moderately bright yellow residual cut fluorescence; light brown residual cut ring; hydrocarbon indicators may be influenced by oil based mud. 3.2.1.7 Hemlock HK3T 10,893’ to 11,031' MD (-9,095' to -9,195' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 181.94 7.08 63.06 87.08 16.85 38.44 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 10,897 9,257.7 87.07 15,752 904 475 60 122 27 28 Conglomerate Sandstone / Conglomerate Sand / Tuffaceous Sandstone / Siltstone 10900' - 11040') = dusky yellowish brown to grayish black to moderate brown hues to olive gray; unconsolidated to firm friable; predominantly upper coarse to lower fine grained; very common 2-3mm grains; very poorly to poorly sorted; sub-angular to sub-rounded; sub- spherical to sub-discoidal; trace bit broken grains; translucent to clear, quartz dominated; carbonaceous sediment common; siltstones are typically dark grayish black to olive black; poor induration; semi -tough to brittle, crumbly; blocky to irregular to earthy fracture; platy to tabular cuttings habit with PDC bit buttercurl cuttings in the higher clay content clasts; gritty to granular texture; minor claystone throughout; petroleum odor masked by LVT oil based mud; even bright yellow sample fluorescence; fast bright white-yellow cut fluorescence with faint yellow streamers; medium straw-light brown visible cut; moderately bright yellow residual cut fluorescence; light brown residual cut ring; hydrocarbon indicators may be influenced by oil based mud. TBU M-28RD 16 3.2.1.8 Hemlock HK4T 11,031’ to 11,153' MD (-9,195' to -9,270' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 86.82 5.43 50.82 52.75 14.36 33.03 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N No notable gas peaks Conglomerate Sand (11050' - 11190') = overall light to medium olive gray to light olive brown; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; dominantly upper coarse to lower coarse, scattered upper medium to occasionally sub- granular size fragments; very poor to poor sorting; dominantly very angular to angular, rare sub-angular to sub-rounded; dominantly low to very low sphericity scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have crypto-crystalline, chert-like texture; even moderately dull yellow sample fluorescence; petroleum odor masked by oil based mud; trace oil stain; moderately fast yellow streamers; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; oil indicators maybe influenced by oil based mud. 3.2.1.9 Hemlock HK5T 11,153’ to 11,416' MD (-9,270' to -9,379' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 209.03 1.07 63.00 67.93 11.58 28.73 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,187 9,447.0 56.80 9,153 617 307 50 87 23 28 11,352 9,518.2 66.06 13,831 618 192 26 41 6 0 Sand (11190' - 11290') = overall light to medium olive gray to light olive brown; milky, off white, transparent, and occasionally light green individual grains; lower medium to upper fine, scattered lower coarse and lower fine; dominant quartz framework with occasional dark lithics and rare micas; fair to poor sorting; dominantly sub- angular to sub-rounded; low to moderate sphericity; unconsolidated; grain support; petroleum odor masked by oil based mud; dull yellow sample fluorescence; weak whitish yellow cut fluorescence with v ery slow faint streamers; faint to light straw visible cut; very faint straw residual cut ring; moderate dull yellow residual cut fluorescence; oil indicators maybe influenced by oil based mud. Conglomerate Sand (11290' - 11470') = overall light to medium olive gray to light olive brown, trace moderate red to red-orange; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; dominantly upper coarse to lower coarse, scattered upper medium to occasionally sub-granular size fragments; very poorly to poorly sorted; dominantly very TBU M-28RD 17 angular to angular, rare sub-angular to sub-rounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert-like texture; even moderately dull yellow sample fluorescence; petroleum odor masked by oil based mud; trace oil stain; moderately fast yellow streamers; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based drilling fluid. 3.2.1.10 Hemlock HK6T 11,416’ to 11,687' MD (-9,379' to -9,448' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 356.31 3.83 136.03 119.59 11.89 42.83 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,425 9,541.2 97.36 19,640 1,115 654 112 171 41 37 11,664 9,601.7 119.59 16,310 735 458 88 186 51 57 Sand / Sandstone (11470' - 11630') = overall light to medium olive gray to light olive brown; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; trace scattered red to red-orange; dominantly upper coarse to lower coarse, scattered upper medium to occasionally sub-granular size fragments; very poorly to poorly sorted; dominantly very angular to angular, rare sub-angular to sub-rounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert-like texture; even moderately dull yellow sample fluorescence; petroleum odor masked by oil based mud; trace oil stain; moderately fast yellow streamers; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. 3.2.1.11 Hemlock HK7T 11,687’ to 11,799' MD (-9,448' to -9,477' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 282.40 7.34 131.70 111.14 10.02 43.35 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,716 9,614.9 111.14 20,693 1487 924 117 268 58 60 11,756 9,625.2 57.60 11,056 701 430 53 126 29 33 Sand / Sandstone (11630' - 11730') = overall light to medium olive brown to light to medium olive gray; dominantly milky, light gray and transparent individual grains, scattered light green; upper fine to lower medium, scattered lower coarse and very fine grains; dominantly quartz frame- work with scattered calcite and dark lithics; dominantly sub-angular to sub-rounded; low to occasionally moderate sphericity; sand is TBU M-28RD 18 unconsolidated with grain support; sandstone is firm to occasionally moderately hard, very weak spotty calcite cement; petro odor masked by oil based mud; even moderate bright yellow sample fluorescence; whitish yellow cut fluorescence with bright yellow moderately fast streamers; scattered oil stain; dark straw to light brown visible cut; moderately bright yellow residual cut fluorescence; medium straw to light brown residual cut ring; oil indicators maybe influenced by oil based mud. TBU M-28RD 19 3.2.1.12 West Foreland Formation The West Foreland formation is comprised mainly of tuffaceous sand, tuffaceous sandstone, and tuffaceous siltstones and occasional tuffaceous claystone and coal beds. The tuffaceous sand/sandstones are medium gray to pale yellowish brown to light olive gray, with lesser white to buff -colored feldspar and black lithic constituents; upper fine to medium to lower coarse grained, with occasional very coarse grains; poor to fair sorting; angular to sub-angular to sub-rounded to rounded; moderate to high sphericity; often interbedded with tuffaceous siltstone/claystone, sometimes micro- laminated; often interbedded with thin coals and carbonaceous shale. The tuffaceous siltstones are light olive gray to pale yellowish brown, also light olive gray to medium gray; they often contain platy and fissile fragments of tuffaceous siltstone and smaller milky pale grains of tuffaceous claystone; occasional clasts of fine to medium grained tuffaceous sandstone and minor coal pieces; a few sub-angular fine to medium sized clear to light blue quartz sand grains; often interbedded with tuffaceous claystone, tuffaceous sandstone, loose sand, and occasional coals and carbonaceous shale. 3.2.1.13 West Foreland H1X_FW 11,799’ to 12,385' MD (-9,477' to -9,572' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 292 6.04 147.66 87.34 12.12 37.44 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 11,873 9,653 87.34 16,116 1,378 701 103 217 53 59 12,196 9,705 69.50 13,372 846 534 78 1,808 43 50 Claystone (11770' - 11820') = dusky yellowish green to dusky green, light to medium olive gray; moderately soft to soft; crumbly to slightly sectile tenacity; irregular earthy fracture; sub-tabular and regular PDC style cutting habit; dull earthy luster; slightly smooth to clayey texture, occasionally slightly silty; non calcareous; petro odor masked by oil based mud; dull yellow sample fluorescence; moderately weak whitish yellow cut fluorescence with moderately bright yellow streamers; moderately dark straw visible cut; bright yellow residual cut fluorescence; light to medium brown residual cut ring; oil indicators maybe influenced by oil based mud. Sand (11860' - 11970') = overall light to medium olive brown to light to medium olive gray; dominantly milky, transparent, pale gray individual grains occasionally light to medium green; dominant quartz framework with rare dark lithics; lower fine to lower medium, common lower coarse and very fine grains; sub-angular to sub-rounded, common angular; low to moderate sphericity; poor to fair sorting; unconsolidated; trace micas; even bright yellow sample fluorescence; whitish yellow cut fluorescence with yellow moderately fast streamers; scattered oil stain; dark straw to light brown visible cut; moderately bright yellow residual cut fluorescence; medium straw to light brown residual cut ring; oil indicators maybe influenced by oil based mud. TBU M-28RD 20 Sand (11970' - 12090') = overall light to medium olive brown to light to medium olive gray; dominantly off white, milky, light gray and transparent individual grains, scattered light green; lower fine to upper medium, scattered lower coarse and very fine grains; dominantly quartz frame- work with scattered dark lithics; dominantly sub-angular to sub-rounded, common angular grains; moderate to low sphericity; unconsolidated; sandstone in sample is firm friable to occasionally firm; grain support with scattered clayey matrix; occasional oil stain on fresh surface; petro odor masked by oil based mud; even moderate bright yellow sample fluorescence; whitish yellow cut fluorescence with moderate bright yellow slow streamers; dark straw to light brown visible cut; moderately bright yellow residual cut fluorescence; medium straw to light brown residual cut ring; oil indicators maybe influenced by oil based mud. Sandstone (12120' - 12230') = overall light to medium olive gray to light to medium olive brown; firm friable to occasionally m oderately hard; upper fine to lower medium; fair to moderate sorting; sub-angular to sub-rounded; moderate sphericity; dominant quartz matrix with rare calcite and dark lithics, trace micas; grain support with occasional clay and tuffaceous matrix; overall non calcareous; occasional imbedded carbonaceous material; petro odor masked by oil based mud; even moderately bright yellow sample fluorescence; moderate bright yellowish white cut fluorescence; faint to very faint straw visible cut; faint brown residual cut ring; moderate yellow residual cut fluorescence; occasional oil stain on fresh surface; oil indicators maybe influenced by oil based mud. Sand (12240' - 12360') = overall light to medium olive gray to light olive brown; dominantly off white, milky, translucent/transparent and light gray individual grains, occasional light green; lower fine to lower medium, occasional lower coarse; quartz framework with occasional micas and dark lithics; dominantly sub-angular to sub-rounded; moderate sphericity; fair sorting; non-calcareous; petroleum odor masked by oil based mud; even, moderately bright yellow sample fluorescence; moderate bright yellow- white cut fluorescence; f aint to very faint straw colored visible cut; faint brown residual cut ring; moderate yellow residual cut fluorescence; occasional oil staining on fresh surfaces; oil indicators maybe influenced by oil based mud. 3.2.1.14 West Foreland WF_2 12,385’ to 13,311' MD (-9,572' to -9,688' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 223.32 5.26 128.90 120.85 5.0 40.51 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 12,471 9,742 120.85 22,650 1719 1,079 159 315 71 73 13,285 9,844 79.83 13,969 1549 882 102 237 46 51 Carbonaceous Shale (12360' - 12410') = black to brownish black to brownish gray as fine disseminated carbonaceous material inter-bedded in shale; shale grades to and inter-bedded with a less indurated carbonaceous claystone/siltstone; moderate to low density; crumbly to firm friable; tabular to cuttings; dull luster; matte texture; non-calcareous; very dull yellow to no fluorescence. Tuffaceous Claystone (12410' - 12470') = light olive gray to medium dark gray fragments of shale, platy tuffaceous claystone and tuffaceous siltstone with occasional micro-bedding; inter-bedded with few stray fine to coarse sand grains scattered throughout and vary in abundance vertically; sand grains are mostly clear quartz with trace yellow- green secondary hues; common PDC bit buttercurl cuttings with higher claystone content; non-calcareous; very dull yellow to no fluorescence. TBU M-28RD 21 Tuffaceous Sandstone (12470' - 12600') = overall light to medium olive brown to light to medium olive gray; dominantly milky, light gray and transparent individual grains, scattered light green; upper fine to lower medium grained, scattered lower coarse and very fine grains; dominantly quartz frame- work with scattered calcite and dark lithics; dominantly sub-angular to sub-rounded; low to occasionally moderate sphericity; often unconsolidated with grain support; sandstone is firm to occasionally moderately hard, very weak spotty calcite cement; petroleum odor masked by oil based mud; even moderate bright yellow sample fluorescence; whitish yellow cut fluorescence with bright yellow moderately fast streamers; scattered oil staining; dark straw to light brown visible cut; moderately bright yellow residual cut fluorescence; medium straw to light brown residual cut ring; hydrocarbon indicators possibly masked by oil based mud. Conglomerate Sand (12600' - 12740') = overall light to medium olive gray to light olive brown; dominantly milky, sub-transparent to transparent, white to off white individual grains, scattered light to medium green; dominantly upper coarse to lower coarse, scattered upper medium to occasionally sub- granular size fragments; very poorly to poorly sorted; dominantly very angular to angular, rare sub- angular to sub-rounded; dominantly low to very low sphericity, scattered irregular; unconsolidated; quartz framework with rare dark lithics; light to medium green fragments have cryptocrystalline, chert-like texture; even moderately dull yellow sample fluorescence; petroleum odor masked by oil based mud; trace oil staining; moderately fast yellow streamers; dull yellow moderately weak cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based mud. Tuffaceous Sandstone / Tuffaceous Siltstone / Sand (12740' - 12850') = light olive gray to moderate olive brown; fragile massive clumps of clay-supported tuffaceous siltstone and fine to medium grained tuffaceous sandstone; with occasional medium to very coarse sand grains interspersed throughout, mostly quartz; minor coal particles of all sizes; intact sandstone clusters are sub-equal quantities of quartz, feldspar -spar and black lithics; petroleum odor masked by oil based mud; trace oil staining; moderately fast yellow streamers; dull yellow-white moderate cut fluorescence; dark straw to light brown visible cut; faint brown to medium straw residual cut ring; moderately dull yellow residual cut fluorescence; hydrocarbon indicators possibly masked by oil based drilling fluid. Sand / Tuffaceous Sandstone (12850' - 1260') = overall light brown to light olive gray, light olive brown; milky, transparent, light gray and occasional light green individual grains; upper fine to lower medium; dominantly quartz framework with rare micas and dark lithics; tuffaceous sandstone has white mushy clayey matrix; friable to soft; crumbly tenacity; sub-angular to sub-rounded; moderate to moderately low sphericity; fair to poor sorting; non calcareous; petro odor masked by oil based mud; even moderately bright yellow sample fluorescence; whitish yellow cut fluorescence; light brown to medium straw visible cut; light brown residual cut ring; moderately bright yellow residual cut fluorescence; trace oil stain; oil indicators maybe influenced by oil based mud. Conglomerate Sand (12960' - 13060') = light to medium olive gray to light olive brown; milky, off -white, light gray, light green and transparent individual grains; lower fine to upper coarse, scattered very coarse grains; angular to sub-angular; low sphericity; low to poor sorting; scattered rounded broken fragments of apparent pebbles; occasional sub-sucrosic texture; unconsolidated; dominantly grain support with common tuff matrix; dominant quartz framework with occasional feldspar and micas; non calcareous; petro odor masked by oil based mud; moderate bright yellow sample fluorescence; fast whitish yellow cut fluorescence; light brown visible cut; scattered oil stain; light brown residual cut ring; moderate bright yellow residual cut fluorescence; oil indicators maybe influenced by oil based mud. Sand (13070' - 13150') = overall light to medium olive gray to light olive brown; dominantly off white, milky, transparent, light green and light gray individual grains; lower fine to lower medium; quartz framework with scattered feldspar and occasional micas; dominantly sub-rounded to sub-angular; moderate sphericity; fair sorting; non calcareous; grain support; petro odor masked by oil based mud; moderately bright yellow sample fluorescence; moderate bright yellow cut fluorescence; faint to very straw TBU M-28RD 22 visible cut; faint brown residual cut ring; moderate yellow cut fluorescence; oil indicators maybe influenced by oil based mud. Sandstone / Conglomerate Sand (13160' - 13260') = overall light to med olive brown to olive gray; clear, milky, light gray, and green individual grains; very coarse to lower medium; poor sorting; very angular to sub-angular, occasional sub-rounded; low sphericity; quartz framework with scattered feldspar and rare micas, dark lithics; unconsolidated; sandstone is lower fine to lower medium; sub-rounded to sub-angular; moderate sphericity; grain support; non calcareous; common oil stain on fresh surface; petro odor masked by oil based mud; moderately bright yellow sample fluorescence; slow moderately bright yellowish white cut fluorescence; dark straw visible cut; moderately bright yellow residual cut fluorescence; medium brown residual cut ring; oil indicators maybe influenced by oil based mud 3.2.1.15 West Foreland WF_3 13,311’ to 13,636' MD (-9,688' to -9,804' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 109 6.05 75.45 33.81 10.01 18.04 Gas Peaks MD Depth TVD Depth Total Gas C1 C2 C3 C4I C4N C5I C5N 13,342 9,851.6 33.81 5,757 411 200 21 68 17 25 Conglomerate Sand (13290' - 13400') = light to medium olive gray to light olive brown; milky, off -white, light gray, light green and transparent individual grains; lower fine to upper coarse, scattered very coarse grains; angular to sub-angular; low sphericity; low to poor sorting; scattered rounded broken fragments of apparent pebbles; occasional sub-sucrosic texture; unconsolidated; dominantly grain support with common tuff matrix; dominant quartz framework with occasional feldspar and micas; non calcareous; petro odor masked by LVT; moderately bright yellow sample fluorescence; slow bright yellowish white cut fluorescence initially becoming moderate whitish yellow with time; faint to light straw visible cut; scattered oil stain; faint brown residual cut ring; moderate yellow residual cut fluorescence; oil indicators maybe influenced by oil based mud. Sandstone / Conglomerate Sand (13400' - 13530') = overall light to medium olive gray to olive brown; clear, milky, light gray, light to medium green individual grains; very coarse to lower medium; poor sorting; very angular to angular, occasionally sub- rounded; low sphericity; dominantly quartz framework with scattered feldspar and rare micas, dark lithics; unconsolidated; sandstone is upper fine to lower medium; sub-rounded to sub-angular; moderate sphericity; grain support; non calcareous; common oil stain on fresh surface; petro odor masked by oil based mud; moderately even bright yellow sample fluorescence; bright yellowish white cut fluorescence with slow bright yellow streamers; light straw visible cut; faint brown residual cut ring; moderate yellow residual cut fluorescence; oil indicators maybe influenced by oil based mud. Sandstone / Conglomerate sand (13530' - 13639') = overall light to medium olive gray to olive brown; clear, milky, light gray, light to medium green individual grains; very coarse to lower medium grained; poorly sorted; very angular to angular, occasionally sub-rounded; low sphericity; dominantly quartz framework with scattered feldspar and rare micas, dark lithic fragments; unconsolidated; sandstone is upper fine to lower medium; sub-rounded to sub-angular; moderate sphericity; grain supported; non- calcareous; common oil staining on fresh surfaces; petroleum odor masked by oil based mud; moderately even bright yellow sample fluorescence; bright yellow-white cut fluorescence with slow bright yellow streamers; light straw visible cut; faint brown residual cut ring; moderate yellow residual cut fluorescence; hydrocarbon indicators maybe influenced by oil based mud. TBU M-28RD 23 3.3 SAMPLING PROGRAM Set Type and Purpose Interval Frequency Distribution A Washed and Dried Reference 8,550’ – 11,000’ 11,000’ – 13,590’ 30’ *10’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference 8,550’ – 11,000’ 11,000’ – 13,590’ 30’ *10’ Debra Oudean Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Box 1: 8,850’ – 9,780’ Box 2: 9,780’ – 11,080’ Box 3: 11,080’ – 12,360’ Box 4: 12,360’ – 13,590’ *Note: 10’ samples were caught as the drill rate allowed; if the drilling rate was faster than 60’/hour, 20’ and 30’ samples were caught. TBU M-28RD 24 4 DRILLING DATA 4.1 SURVEYS Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 25.0 0.12 333.98 25.00 0.02 -0.01 0.02 0.48 50.0 0.24 333.98 50.00 0.09 -0.05 0.08 0.48 75.0 0.19 288.99 75.00 0.15 -0.11 0.11 0.68 100.0 0.33 132.26 100.00 0.12 -0.09 0.08 2.04 125.0 0.27 107.13 125.00 0.05 0.02 0.06 0.57 150.0 0.18 52.60 150.00 0.06 0.10 0.09 0.88 175.0 0.03 201.83 175.00 0.08 0.13 0.12 0.83 200.0 0.06 274.30 200.00 0.07 0.12 0.11 0.23 225.0 0.38 157.77 225.00 0.00 0.13 0.04 1.64 250.0 0.12 47.75 250.00 -0.06 0.19 0.00 1.74 275.0 0.27 61.33 275.00 -0.02 0.26 0.06 0.62 300.0 0.19 74.03 300.00 0.02 0.35 0.13 0.38 325.0 0.24 132.87 325.00 0.00 0.43 0.13 0.86 350.0 0.67 114.21 350.00 -0.10 0.60 0.09 1.80 375.0 0.54 84.48 375.00 -0.14 0.85 0.12 1.34 400.0 0.68 98.16 399.99 -0.15 1.11 0.20 0.80 425.0 0.82 102.19 424.99 -0.21 1.43 0.24 0.60 450.0 1.04 106.91 449.99 -0.32 1.83 0.26 0.93 475.0 0.96 105.78 474.99 -0.44 2.24 0.28 0.33 500.0 1.32 108.72 499.98 -0.59 2.72 0.28 1.46 525.0 1.35 105.44 524.97 -0.76 3.28 0.29 0.33 550.0 1.52 101.52 549.97 -0.90 3.88 0.34 0.78 575.0 1.63 105.12 574.96 -1.06 4.55 0.40 0.59 600.0 1.70 100.56 599.95 -1.22 5.26 0.46 0.60 625.0 1.84 91.18 624.93 -1.30 6.03 0.63 1.29 650.0 2.08 88.88 649.92 -1.30 6.88 0.89 1.01 675.0 2.23 82.56 674.90 -1.23 7.82 1.25 1.12 700.0 2.24 82.63 699.88 -1.10 8.78 1.67 0.04 725.0 2.00 84.05 724.87 -0.99 9.70 2.06 0.98 750.0 2.13 87.13 749.85 -0.93 10.60 2.40 0.68 775.0 2.07 90.30 774.83 -0.91 11.52 2.70 0.52 800.0 2.13 82.44 799.82 -0.85 12.43 3.04 1.18 825.0 1.99 74.96 824.80 -0.67 13.31 3.48 1.21 850.0 1.87 83.70 849.79 -0.52 14.13 3.88 1.27 TBU M-28RD 25 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 875.0 1.87 72.29 874.77 -0.35 14.93 4.29 1.49 900.0 1.94 74.92 899.76 -0.11 15.72 4.76 0.45 925.0 2.08 75.35 924.74 0.11 16.57 5.23 0.56 950.0 2.16 65.27 949.73 0.42 17.44 5.80 1.52 975.0 2.31 64.19 974.71 0.84 18.32 6.47 0.62 1,000.0 2.64 61.49 999.68 1.34 19.28 7.23 1.40 1,025.0 2.93 55.88 1,024.65 1.97 20.31 8.16 1.59 1,050.0 2.77 59.01 1,049.62 2.64 21.36 9.12 0.89 1,075.0 2.87 56.09 1,074.59 3.30 22.40 10.06 0.70 1,100.0 2.91 50.07 1,099.56 4.05 23.40 11.10 1.22 1,125.0 2.97 43.09 1,124.53 4.93 24.33 12.22 1.45 1,150.0 3.07 34.42 1,149.49 5.96 25.15 13.45 1.87 1,175.0 3.29 27.44 1,174.46 7.15 25.86 14.80 1.78 1,200.0 3.69 22.51 1,199.41 8.53 26.50 16.31 2.00 1,225.0 4.26 16.60 1,224.35 10.16 27.07 18.04 2.80 1,250.0 4.84 12.02 1,249.27 12.08 27.56 20.02 2.74 1,275.0 5.62 9.95 1,274.17 14.32 27.99 22.28 3.21 1,300.0 6.50 9.42 1,299.03 16.92 28.43 24.89 3.53 1,325.0 7.10 9.83 1,323.85 19.84 28.93 27.82 2.41 1,350.0 7.86 11.44 1,348.64 23.04 29.53 31.04 3.15 1,375.0 8.46 11.80 1,373.38 26.51 30.25 34.57 2.41 1,400.0 9.19 12.53 1,398.09 30.26 31.06 38.39 2.95 1,425.0 9.53 12.42 1,422.75 34.23 31.93 42.43 1.36 1,450.0 9.95 12.34 1,447.39 38.36 32.84 46.64 1.68 1,475.0 10.10 12.37 1,472.01 42.62 33.77 50.97 0.60 1,500.0 10.64 12.03 1,496.60 47.01 34.72 55.45 2.17 1,525.0 11.33 12.51 1,521.15 51.67 35.74 60.19 2.78 1,550.0 12.50 12.68 1,545.61 56.71 36.86 65.33 4.68 1,575.0 13.60 13.07 1,569.96 62.21 38.12 70.95 4.41 1,600.0 14.57 13.87 1,594.21 68.12 39.54 77.01 3.96 1,625.0 15.55 14.56 1,618.35 74.42 41.14 83.50 3.98 1,650.0 16.48 15.11 1,642.38 81.09 42.90 90.38 3.77 1,675.0 17.23 15.86 1,666.31 88.07 44.84 97.62 3.12 1,700.0 17.90 16.77 1,690.14 95.31 46.96 105.16 2.90 1,725.0 18.49 17.38 1,713.89 102.78 49.25 112.97 2.48 1,750.0 19.12 18.31 1,737.56 110.45 51.72 121.03 2.79 1,775.0 20.01 19.44 1,761.11 118.37 54.43 129.40 3.87 1,800.0 20.81 20.18 1,784.54 126.57 57.39 138.11 3.36 TBU M-28RD 26 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 1,825.0 21.69 20.58 1,807.84 135.06 60.54 147.17 3.57 1,850.0 22.45 20.87 1,831.01 143.85 63.87 156.55 3.07 1,875.0 22.94 20.67 1,854.07 152.87 67.29 166.18 1.98 1,900.0 23.29 20.58 1,877.07 162.05 70.75 175.99 1.41 1,925.0 23.94 20.75 1,899.97 171.42 74.28 185.99 2.61 1,950.0 24.51 21.11 1,922.77 181.00 77.94 196.24 2.36 1,975.0 24.61 21.23 1,945.51 190.69 81.70 206.61 0.45 2,000.0 24.88 21.08 1,968.21 200.45 85.47 217.06 1.11 2,025.0 25.23 20.98 1,990.86 210.33 89.27 227.63 1.41 2,050.0 25.88 20.88 2,013.42 220.41 93.12 238.40 2.61 2,075.0 26.76 20.68 2,035.82 230.77 97.06 249.47 3.54 2,100.0 27.99 20.54 2,058.02 241.53 101.10 260.96 4.93 2,125.0 29.10 20.54 2,079.98 252.72 105.29 272.89 4.44 2,150.0 30.14 20.89 2,101.72 264.27 109.67 285.23 4.22 2,175.0 31.21 21.22 2,123.22 276.18 114.25 297.97 4.33 2,200.0 31.85 21.61 2,144.53 288.35 119.02 311.02 2.69 2,225.0 32.74 21.83 2,165.66 300.75 123.97 324.35 3.59 2,250.0 33.66 22.27 2,186.58 313.44 129.11 338.01 3.80 2,275.0 34.30 22.49 2,207.31 326.36 134.43 351.94 2.61 2,300.0 34.96 22.58 2,227.88 339.48 139.87 366.10 2.65 2,325.0 35.65 22.77 2,248.28 352.81 145.44 380.50 2.79 2,350.0 36.48 23.03 2,268.49 366.37 151.17 395.16 3.38 2,375.0 37.53 23.33 2,288.46 380.20 157.09 410.15 4.26 2,400.0 38.01 23.63 2,308.22 394.25 163.19 425.39 2.06 2,425.0 38.54 23.78 2,327.84 408.43 169.42 440.80 2.15 2,450.0 39.09 23.92 2,347.32 422.76 175.75 456.39 2.23 2,475.0 39.24 23.94 2,366.71 437.19 182.16 472.10 0.60 2,500.0 39.30 23.96 2,386.06 451.65 188.58 487.84 0.25 2,525.0 39.45 24.08 2,405.39 466.14 195.04 503.61 0.67 2,550.0 39.82 24.10 2,424.64 480.70 201.55 519.47 1.48 2,575.0 40.01 24.11 2,443.81 495.34 208.10 535.42 0.76 2,600.0 39.84 24.03 2,462.99 509.99 214.64 551.37 0.71 2,625.0 39.73 24.01 2,482.20 524.60 221.15 567.28 0.44 2,650.0 39.64 24.10 2,501.44 539.18 227.66 583.16 0.43 2,675.0 39.60 24.06 2,520.69 553.74 234.17 599.01 0.19 2,700.0 39.52 23.88 2,539.97 568.28 240.63 614.85 0.56 2,725.0 39.30 23.96 2,559.28 582.79 247.07 630.64 0.90 2,750.0 39.26 24.03 2,578.64 597.25 253.51 646.38 0.24 TBU M-28RD 27 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2,775.0 39.29 24.01 2,597.99 611.71 259.95 662.12 0.13 2,800.0 39.26 24.06 2,617.34 626.16 266.39 677.86 0.17 2,825.0 39.24 24.02 2,636.70 640.61 272.84 693.59 0.13 2,850.0 39.09 24.01 2,656.08 655.03 279.26 709.29 0.60 2,875.0 38.84 23.99 2,675.52 669.39 285.66 724.92 1.00 2,900.0 38.99 24.03 2,694.97 683.74 292.05 740.54 0.61 2,925.0 38.89 24.03 2,714.42 698.09 298.45 756.17 0.40 2,950.0 38.69 23.88 2,733.91 712.40 304.81 771.75 0.88 2,975.0 38.76 23.91 2,753.41 726.70 311.14 787.30 0.29 3,000.0 38.48 24.03 2,772.94 740.96 317.48 802.82 1.16 3,025.0 38.59 24.04 2,792.50 755.18 323.82 818.31 0.44 3,050.0 38.52 23.99 2,812.05 769.42 330.16 833.81 0.31 3,075.0 38.57 23.87 2,831.60 783.65 336.48 849.31 0.36 3,100.0 38.42 23.91 2,851.17 797.88 342.78 864.79 0.61 3,125.0 38.36 24.09 2,870.76 812.07 349.10 880.23 0.51 3,150.0 38.45 24.11 2,890.35 826.24 355.44 895.67 0.36 3,175.0 38.45 24.08 2,909.93 840.43 361.79 911.13 0.07 3,200.0 38.31 23.86 2,929.53 854.62 368.09 926.57 0.78 3,225.0 38.20 23.97 2,949.16 868.77 374.37 941.96 0.52 3,250.0 38.06 23.85 2,968.83 882.88 380.62 957.32 0.63 3,275.0 38.07 23.87 2,988.51 896.97 386.86 972.65 0.06 3,300.0 38.10 23.87 3,008.19 911.08 393.10 987.99 0.12 3,325.0 38.02 23.79 3,027.87 925.17 399.33 1,003.32 0.38 3,350.0 37.86 23.92 3,047.59 939.23 405.54 1,018.62 0.72 3,375.0 37.60 24.11 3,067.36 953.21 411.77 1,033.83 1.14 3,400.0 37.55 24.28 3,087.17 967.11 418.02 1,048.99 0.46 3,425.0 37.52 24.30 3,107.00 981.00 424.28 1,064.13 0.13 3,450.0 37.30 24.25 3,126.86 994.84 430.53 1,079.22 0.89 3,475.0 37.28 24.40 3,146.75 1,008.64 436.77 1,094.28 0.37 3,500.0 37.36 24.41 3,166.63 1,022.44 443.03 1,109.34 0.32 3,525.0 37.38 24.46 3,186.50 1,036.26 449.30 1,124.42 0.15 3,550.0 37.27 24.50 3,206.38 1,050.05 455.59 1,139.48 0.45 3,575.0 37.32 24.31 3,226.26 1,063.85 461.85 1,154.54 0.50 3,600.0 37.24 24.39 3,246.16 1,077.64 468.09 1,169.59 0.37 3,625.0 37.29 24.45 3,266.05 1,091.43 474.35 1,184.63 0.25 3,650.0 37.32 24.32 3,285.94 1,105.23 480.60 1,199.69 0.34 3,675.0 37.26 24.34 3,305.83 1,119.03 486.84 1,214.74 0.24 3,700.0 37.03 24.47 3,325.76 1,132.78 493.08 1,229.75 0.97 TBU M-28RD 28 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 3,725.0 36.95 24.49 3,345.72 1,146.47 499.31 1,244.69 0.32 3,750.0 37.17 24.67 3,365.67 1,160.17 505.58 1,259.66 0.98 3,775.0 37.29 24.58 3,385.58 1,173.92 511.88 1,274.68 0.53 3,800.0 37.17 24.55 3,405.48 1,187.67 518.17 1,289.71 0.49 3,825.0 37.03 24.56 3,425.42 1,201.39 524.44 1,304.69 0.56 3,850.0 36.90 24.59 3,445.40 1,215.06 530.69 1,319.63 0.52 3,875.0 36.74 24.59 3,465.41 1,228.68 536.92 1,334.51 0.64 3,900.0 36.60 24.58 3,485.46 1,242.26 543.14 1,349.34 0.56 3,925.0 36.68 24.52 3,505.52 1,255.83 549.33 1,364.17 0.35 3,950.0 36.47 24.45 3,525.60 1,269.39 555.51 1,378.97 0.86 3,975.0 36.49 24.27 3,545.70 1,282.93 561.64 1,393.74 0.44 4,000.0 36.63 24.12 3,565.78 1,296.51 567.74 1,408.55 0.66 4,025.0 36.67 23.70 3,585.84 1,310.16 573.79 1,423.39 1.02 4,050.0 36.75 23.28 3,605.88 1,323.86 579.75 1,438.27 1.05 4,075.0 36.94 23.05 3,625.89 1,337.64 585.64 1,453.20 0.94 4,100.0 37.14 22.79 3,645.84 1,351.51 591.51 1,468.20 1.02 4,125.0 37.43 22.62 3,665.74 1,365.48 597.35 1,483.30 1.23 4,150.0 37.72 22.38 3,685.55 1,379.57 603.19 1,498.50 1.30 4,175.0 37.57 21.85 3,705.34 1,393.72 608.94 1,513.73 1.43 4,200.0 37.71 21.71 3,725.14 1,407.89 614.60 1,528.96 0.66 4,225.0 37.92 21.67 3,744.89 1,422.14 620.27 1,544.26 0.85 4,250.0 38.14 21.57 3,764.58 1,436.45 625.94 1,559.63 0.91 4,275.0 38.26 21.55 3,784.23 1,450.83 631.62 1,575.06 0.48 4,300.0 38.44 21.57 3,803.84 1,465.26 637.32 1,590.54 0.72 4,325.0 38.61 21.56 3,823.39 1,479.74 643.05 1,606.08 0.68 4,350.0 39.04 21.57 3,842.87 1,494.32 648.81 1,621.73 1.72 4,375.0 39.32 21.49 3,862.25 1,509.01 654.60 1,637.49 1.14 4,400.0 39.51 21.51 3,881.56 1,523.78 660.42 1,653.33 0.76 4,425.0 39.58 21.22 3,900.84 1,538.60 666.22 1,669.22 0.79 4,450.0 39.74 21.10 3,920.09 1,553.48 671.98 1,685.16 0.71 4,475.0 39.96 20.93 3,939.28 1,568.43 677.72 1,701.15 0.98 4,500.0 40.04 20.65 3,958.43 1,583.46 683.43 1,717.20 0.79 4,525.0 40.15 20.59 3,977.56 1,598.53 689.10 1,733.29 0.47 4,550.0 40.06 20.52 3,996.68 1,613.61 694.75 1,749.38 0.40 4,575.0 39.93 20.60 4,015.83 1,628.65 700.40 1,765.43 0.56 4,600.0 39.90 20.48 4,035.01 1,643.67 706.02 1,781.46 0.33 4,625.0 40.00 20.47 4,054.17 1,658.71 711.64 1,797.49 0.40 4,650.0 39.98 20.52 4,073.33 1,673.76 717.26 1,813.55 0.15 TBU M-28RD 29 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4,675.0 39.87 20.55 4,092.50 1,688.79 722.89 1,829.57 0.45 4,700.0 40.09 20.58 4,111.65 1,703.83 728.53 1,845.62 0.88 4,725.0 40.43 20.62 4,130.73 1,718.95 734.22 1,861.76 1.36 4,750.0 40.56 20.62 4,149.74 1,734.14 739.94 1,877.98 0.52 4,775.0 40.21 20.45 4,168.79 1,749.31 745.62 1,894.16 1.47 4,800.0 40.25 20.48 4,187.87 1,764.44 751.26 1,910.29 0.18 4,825.0 40.14 20.51 4,206.97 1,779.55 756.91 1,926.41 0.45 4,850.0 40.08 20.50 4,226.09 1,794.64 762.55 1,942.50 0.24 4,875.0 40.12 20.43 4,245.21 1,809.73 768.18 1,958.59 0.24 4,900.0 40.00 20.52 4,264.35 1,824.80 773.81 1,974.67 0.53 4,925.0 39.98 20.51 4,283.50 1,839.85 779.44 1,990.72 0.08 4,950.0 40.11 20.46 4,302.64 1,854.91 785.07 2,006.79 0.54 4,975.0 40.00 20.41 4,321.77 1,869.99 790.69 2,022.86 0.46 5,000.0 40.21 20.40 4,340.90 1,885.08 796.30 2,038.95 0.84 5,025.0 40.36 20.42 4,359.97 1,900.23 801.94 2,055.10 0.60 5,050.0 40.18 20.51 4,379.04 1,915.37 807.59 2,071.25 0.76 5,075.0 40.21 20.54 4,398.14 1,930.48 813.25 2,087.37 0.14 5,100.0 40.28 20.59 4,417.22 1,945.61 818.92 2,103.50 0.31 5,125.0 40.14 20.56 4,436.31 1,960.72 824.59 2,119.63 0.57 5,150.0 39.46 20.66 4,455.52 1,975.69 830.23 2,135.61 2.73 5,175.0 39.25 20.74 4,474.85 1,990.52 835.83 2,151.45 0.86 5,200.0 39.67 20.79 4,494.15 2,005.38 841.46 2,167.32 1.68 5,225.0 39.86 20.78 4,513.37 2,020.33 847.14 2,183.29 0.76 5,250.0 39.89 20.83 4,532.56 2,035.31 852.83 2,199.30 0.18 5,275.0 39.31 20.93 4,551.82 2,050.20 858.51 2,215.22 2.33 5,300.0 39.13 20.93 4,571.19 2,064.97 864.16 2,231.00 0.72 5,325.0 39.12 21.02 4,590.58 2,079.70 869.81 2,246.76 0.23 5,350.0 38.99 20.99 4,609.99 2,094.40 875.45 2,262.49 0.53 5,375.0 38.96 20.92 4,629.43 2,109.09 881.07 2,278.19 0.21 5,400.0 39.21 20.89 4,648.83 2,123.81 886.70 2,293.93 1.00 5,425.0 39.11 20.78 4,668.22 2,138.57 892.31 2,309.70 0.49 5,450.0 38.79 20.81 4,687.66 2,153.26 897.89 2,325.40 1.28 5,475.0 38.26 20.89 4,707.22 2,167.81 903.44 2,340.95 2.13 5,500.0 38.19 20.89 4,726.86 2,182.26 908.95 2,356.40 0.28 5,525.0 38.30 20.92 4,746.49 2,196.72 914.47 2,371.86 0.45 5,550.0 38.53 20.93 4,766.08 2,211.23 920.02 2,387.37 0.92 5,575.0 38.64 20.83 4,785.62 2,225.80 925.58 2,402.94 0.51 5,600.0 38.54 20.76 4,805.17 2,240.37 931.11 2,418.52 0.44 TBU M-28RD 30 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 5,625.0 38.57 20.88 4,824.72 2,254.94 936.65 2,434.08 0.32 5,650.0 38.49 20.72 4,844.27 2,269.50 942.18 2,449.64 0.51 5,675.0 38.41 20.75 4,863.85 2,284.04 947.69 2,465.17 0.33 5,700.0 38.31 20.63 4,883.45 2,298.55 953.17 2,480.66 0.50 5,725.0 38.28 20.55 4,903.08 2,313.05 958.62 2,496.14 0.23 5,750.0 38.33 20.45 4,922.69 2,327.57 964.04 2,511.62 0.32 5,775.0 38.57 20.41 4,942.27 2,342.14 969.47 2,527.16 0.97 5,800.0 38.82 20.34 4,961.78 2,356.79 974.91 2,542.77 1.02 5,825.0 38.82 20.33 4,981.26 2,371.48 980.36 2,558.43 0.03 5,850.0 38.40 20.14 5,000.80 2,386.12 985.75 2,574.02 1.75 5,875.0 38.53 20.11 5,020.37 2,400.72 991.10 2,589.56 0.53 5,900.0 38.83 20.10 5,039.89 2,415.39 996.48 2,605.17 1.20 5,925.0 39.12 20.11 5,059.32 2,430.16 1,001.88 2,620.89 1.16 5,950.0 38.91 19.98 5,078.75 2,444.94 1,007.27 2,636.62 0.90 5,975.0 38.64 20.04 5,098.24 2,459.66 1,012.63 2,652.26 1.09 6,000.0 38.71 20.12 5,117.76 2,474.33 1,018.00 2,667.88 0.34 6,025.0 39.19 20.08 5,137.20 2,489.09 1,023.40 2,683.58 1.92 6,050.0 39.37 20.02 5,156.55 2,503.96 1,028.82 2,699.40 0.74 6,075.0 39.49 20.14 5,175.86 2,518.87 1,034.27 2,715.27 0.57 6,100.0 39.52 20.25 5,195.15 2,533.79 1,039.76 2,731.16 0.30 6,125.0 39.42 20.18 5,214.45 2,548.71 1,045.26 2,747.04 0.44 6,150.0 39.51 20.19 5,233.75 2,563.62 1,050.74 2,762.92 0.36 6,175.0 39.73 20.17 5,253.01 2,578.59 1,056.24 2,778.85 0.88 6,200.0 39.96 20.26 5,272.20 2,593.62 1,061.77 2,794.85 0.95 6,225.0 39.59 20.22 5,291.41 2,608.62 1,067.31 2,810.84 1.48 6,250.0 39.85 20.32 5,310.64 2,623.61 1,072.84 2,826.80 1.07 6,275.0 39.90 20.24 5,329.83 2,638.64 1,078.40 2,842.82 0.29 6,300.0 40.12 20.28 5,348.98 2,653.72 1,083.96 2,858.88 0.89 6,325.0 40.50 20.32 5,368.04 2,668.89 1,089.57 2,875.04 1.52 6,350.0 40.43 20.63 5,387.06 2,684.09 1,095.25 2,891.25 0.85 6,375.0 40.29 20.77 5,406.11 2,699.24 1,100.97 2,907.42 0.67 6,400.0 40.35 20.96 5,425.17 2,714.35 1,106.73 2,923.58 0.55 6,425.0 40.34 21.09 5,444.23 2,729.46 1,112.54 2,939.74 0.34 6,450.0 39.99 21.49 5,463.33 2,744.48 1,118.39 2,955.84 1.74 6,475.0 39.75 21.91 5,482.52 2,759.37 1,124.32 2,971.83 1.44 6,500.0 39.83 22.33 5,501.73 2,774.19 1,130.34 2,987.79 1.12 6,525.0 39.98 22.71 5,520.91 2,789.01 1,136.49 3,003.78 1.14 6,550.0 39.52 22.89 5,540.13 2,803.75 1,142.68 3,019.71 1.90 TBU M-28RD 31 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 6,575.0 39.53 23.01 5,559.41 2,818.40 1,148.89 3,035.56 0.31 6,600.0 39.72 23.09 5,578.67 2,833.07 1,155.13 3,051.44 0.79 6,625.0 40.02 23.11 5,597.85 2,847.81 1,161.42 3,067.40 1.20 6,650.0 40.09 23.28 5,616.99 2,862.60 1,167.75 3,083.43 0.52 6,675.0 39.87 23.46 5,636.15 2,877.34 1,174.12 3,099.42 0.99 6,700.0 39.82 23.75 5,655.34 2,892.02 1,180.54 3,115.36 0.77 6,725.0 40.20 24.11 5,674.49 2,906.71 1,187.06 3,131.35 1.78 6,750.0 40.38 24.50 5,693.56 2,921.44 1,193.71 3,147.42 1.24 6,775.0 40.26 25.00 5,712.62 2,936.14 1,200.48 3,163.48 1.38 6,800.0 40.20 25.25 5,731.71 2,950.75 1,207.34 3,179.50 0.69 6,825.0 40.25 25.43 5,750.79 2,965.35 1,214.25 3,195.52 0.51 6,850.0 40.21 25.44 5,769.88 2,979.93 1,221.18 3,211.53 0.16 6,875.0 40.04 25.45 5,789.00 2,994.48 1,228.11 3,227.51 0.68 6,900.0 40.19 25.50 5,808.12 3,009.02 1,235.03 3,243.48 0.61 6,925.0 40.22 25.48 5,827.21 3,023.58 1,241.98 3,259.48 0.13 6,950.0 40.16 25.34 5,846.31 3,038.16 1,248.90 3,275.48 0.43 6,975.0 40.35 25.28 5,865.39 3,052.76 1,255.81 3,291.50 0.78 7,000.0 40.58 25.13 5,884.41 3,067.44 1,262.72 3,307.60 1.00 7,025.0 40.59 24.61 5,903.39 3,082.20 1,269.56 3,323.75 1.35 7,050.0 40.74 24.34 5,922.36 3,097.02 1,276.31 3,339.93 0.92 7,075.0 40.73 23.60 5,941.30 3,111.93 1,282.94 3,356.16 1.93 7,100.0 40.93 22.85 5,960.22 3,126.95 1,289.38 3,372.44 2.12 7,125.0 41.34 22.33 5,979.05 3,142.14 1,295.70 3,388.83 2.14 7,150.0 41.02 21.77 5,997.86 3,157.39 1,301.88 3,405.25 1.95 7,175.0 41.18 21.42 6,016.70 3,172.67 1,307.93 3,421.65 1.12 7,200.0 40.89 20.77 6,035.56 3,187.99 1,313.83 3,438.04 2.06 7,225.0 40.56 20.20 6,054.50 3,203.26 1,319.54 3,454.34 1.99 7,250.0 40.69 19.91 6,073.48 3,218.56 1,325.12 3,470.61 0.92 7,275.0 40.81 19.85 6,092.42 3,233.90 1,330.67 3,486.92 0.50 7,300.0 40.74 19.97 6,111.35 3,249.25 1,336.23 3,503.23 0.42 7,325.0 40.57 19.93 6,130.32 3,264.56 1,341.79 3,519.51 0.69 7,350.0 40.54 19.92 6,149.31 3,279.84 1,347.33 3,535.76 0.12 7,375.0 40.69 19.99 6,168.29 3,295.14 1,352.88 3,552.02 0.63 7,400.0 40.94 20.05 6,187.21 3,310.49 1,358.48 3,568.35 1.01 7,425.0 41.34 20.16 6,206.04 3,325.94 1,364.13 3,584.79 1.63 7,450.0 41.24 20.15 6,224.82 3,341.43 1,369.82 3,601.28 0.40 7,475.0 41.27 20.07 6,243.62 3,356.91 1,375.48 3,617.75 0.24 7,500.0 41.29 20.14 6,262.40 3,372.40 1,381.15 3,634.23 0.20 TBU M-28RD 32 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 7,525.0 41.36 20.16 6,281.18 3,387.89 1,386.84 3,650.73 0.28 7,550.0 41.51 20.20 6,299.92 3,403.42 1,392.55 3,667.26 0.61 7,575.0 41.39 20.30 6,318.66 3,418.95 1,398.28 3,683.80 0.55 7,600.0 41.31 20.26 6,337.43 3,434.44 1,404.00 3,700.30 0.34 7,625.0 41.20 20.15 6,356.22 3,449.91 1,409.69 3,716.78 0.53 7,650.0 41.04 20.15 6,375.05 3,465.35 1,415.36 3,733.21 0.64 7,675.0 41.38 20.20 6,393.86 3,480.81 1,421.04 3,749.66 1.37 7,700.0 41.43 20.13 6,412.61 3,496.33 1,426.74 3,766.19 0.27 7,725.0 41.34 20.05 6,431.37 3,511.85 1,432.41 3,782.70 0.42 7,750.0 41.20 20.14 6,450.16 3,527.34 1,438.08 3,799.18 0.61 7,775.0 41.32 20.39 6,468.95 3,542.80 1,443.79 3,815.66 0.82 7,800.0 41.33 20.64 6,487.73 3,558.26 1,449.58 3,832.15 0.66 7,825.0 41.32 20.78 6,506.50 3,573.70 1,455.41 3,848.64 0.37 7,850.0 41.37 20.83 6,525.27 3,589.14 1,461.28 3,865.14 0.24 7,875.0 41.26 20.84 6,544.05 3,604.57 1,467.15 3,881.62 0.44 7,900.0 41.16 20.93 6,562.86 3,619.96 1,473.02 3,898.07 0.47 7,925.0 41.50 20.78 6,581.63 3,635.38 1,478.90 3,914.56 1.42 7,950.0 41.63 20.77 6,600.33 3,650.89 1,484.78 3,931.13 0.52 7,975.0 41.40 21.10 6,619.05 3,666.37 1,490.70 3,947.68 1.27 8,000.0 41.54 21.03 6,637.79 3,681.82 1,496.65 3,964.21 0.59 8,025.0 41.35 20.95 6,656.53 3,697.27 1,502.58 3,980.73 0.79 8,050.0 41.62 21.00 6,675.25 3,712.73 1,508.51 3,997.27 1.09 8,075.0 41.94 21.07 6,693.90 3,728.28 1,514.49 4,013.91 1.29 8,100.0 42.27 21.15 6,712.44 3,743.92 1,520.53 4,030.64 1.34 8,125.0 41.91 20.76 6,731.00 3,759.56 1,526.52 4,047.38 1.78 8,150.0 41.75 21.20 6,749.63 3,775.13 1,532.49 4,064.03 1.34 8,175.0 41.95 21.38 6,768.25 3,790.67 1,538.54 4,080.68 0.93 8,200.0 41.84 21.09 6,786.86 3,806.23 1,544.59 4,097.35 0.89 8,225.0 41.34 21.31 6,805.55 3,821.71 1,550.59 4,113.92 2.08 8,250.0 41.43 21.52 6,824.31 3,837.09 1,556.63 4,130.42 0.66 8,275.0 41.37 21.68 6,843.06 3,852.46 1,562.71 4,146.92 0.49 8,300.0 41.23 22.26 6,861.85 3,867.77 1,568.89 4,163.38 1.63 8,325.0 40.96 22.26 6,880.69 3,882.97 1,575.11 4,179.77 1.08 8,350.0 40.49 22.20 6,899.63 3,898.07 1,581.28 4,196.03 1.89 8,375.0 40.18 22.47 6,918.69 3,913.04 1,587.43 4,212.17 1.42 8,400.0 40.57 22.31 6,937.73 3,928.01 1,593.60 4,228.32 1.61 8,425.0 40.58 22.39 6,956.72 3,943.05 1,599.78 4,244.53 0.21 8,450.0 40.65 22.07 6,975.70 3,958.12 1,605.94 4,260.76 0.88 TBU M-28RD 33 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 8,461.0 40.39 21.97 6,984.06 3,964.74 1,608.62 4,267.89 2.44 8,530.0 40.47 20.98 7,036.59 4,006.38 1,625.00 4,312.56 0.94 8,550.0 40.43 21.23 7,051.81 4,018.49 1,629.67 4,325.51 0.84 8,582.94 40.40 20.23 7,076.89 4,038.46 1,637.23 4,346.85 1.97 8,679.42 36.10 16.93 7,152.64 4,095.02 1,656.33 4,406.54 4.93 8,773.69 31.25 12.83 7,231.08 4,145.47 1,669.86 4,458.70 5.68 8,868.60 25.32 7.14 7,314.64 4,189.66 1,677.86 4,503.19 6.86 8,962.24 19.34 3.86 7,401.22 4,225.03 1,681.39 4,537.93 6.52 9,057.87 18.75 2.70 7,491.61 4,256.19 1,683.18 4,568.11 0.73 9,151.86 14.64 355.70 7,581.63 4,283.14 1,683.00 4,593.68 4.87 9,246.54 9.39 338.94 7,674.23 4,302.30 1,679.32 4,610.77 6.60 9,342.11 8.42 342.34 7,768.65 4,316.25 1,674.40 4,622.50 1.16 9,437.15 10.00 349.64 7,862.46 4,330.99 1,670.81 4,635.41 2.07 9,530.93 10.03 348.31 7,954.81 4,347.00 1,667.69 4,649.67 0.25 9,625.23 9.60 346.92 8,047.73 4,362.71 1,664.24 4,663.54 0.52 9,720.25 8.88 348.36 8,141.52 4,377.61 1,660.97 4,676.70 0.80 9,815.48 9.13 353.46 8,235.57 4,392.31 1,658.63 4,689.96 0.88 9,909.75 10.54 354.70 8,328.45 4,408.33 1,656.98 4,704.68 1.51 10,006.30 10.87 356.47 8,423.33 4,426.21 1,655.60 4,721.26 0.48 10,098.04 9.43 349.34 8,513.63 4,442.23 1,653.68 4,735.90 2.08 10,192.62 9.90 345.42 8,606.87 4,457.72 1,650.20 4,749.55 0.86 10,288.78 11.34 343.58 8,701.38 4,474.79 1,645.45 4,764.31 1.54 10,382.97 12.96 346.09 8,793.46 4,493.93 1,640.29 4,780.92 1.81 10,477.69 16.55 355.15 8,885.06 4,517.69 1,636.59 4,802.37 4.49 10,573.63 20.68 0.52 8,975.96 4,548.26 1,635.59 4,831.13 4.66 10,668.03 23.42 5.56 9,063.46 4,583.61 1,637.56 4,865.35 3.52 10,763.15 29.93 6.12 9,148.41 4,626.06 1,641.92 4,907.07 6.85 10,856.33 36.45 7.83 9,226.34 4,676.65 1,648.18 4,957.12 7.07 10,952.57 42.68 10.01 9,300.51 4,737.16 1,657.76 5,017.62 6.63 11,046.29 49.45 12.89 9,365.50 4,803.23 1,671.24 5,084.62 7.55 11,141.82 55.06 13.96 9,423.96 4,876.67 1,688.79 5,159.89 5.94 11,237.79 63.09 14.66 9,473.24 4,956.37 1,709.14 5,241.97 8.40 11,331.93 68.09 14.75 9,512.13 5,039.27 1,730.89 5,327.53 5.30 11,427.84 75.14 12.72 9,542.37 5,127.62 1,752.45 5,418.23 7.62 11,521.11 75.55 9.69 9,565.97 5,216.13 1,769.98 5,507.81 3.17 11,616.08 75.36 8.76 9,589.82 5,306.87 1,784.72 5,598.66 0.97 11,710.57 75.10 9.22 9,613.91 5,397.11 1,799.00 5,688.89 0.55 11,804.69 75.30 10.09 9,637.96 5,486.82 1,814.26 5,778.92 0.91 TBU M-28RD 34 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 11,894.19 78.16 10.40 9,658.50 5,572.53 1,829.75 5,865.22 3.21 11,993.11 81.06 11.20 9,676.34 5,668.09 1,847.98 5,961.73 3.04 12,087.81 81.98 11.92 9,690.31 5,759.85 1,866.75 6,054.80 1.23 12,182.81 82.04 14.73 9,703.51 5,851.39 1,888.43 6,148.56 2.93 12,278.59 81.91 14.85 9,716.88 5,943.09 1,912.65 6,243.25 0.18 12,372.05 82.05 16.86 9,729.92 6,032.11 1,937.93 6,335.72 2.14 12,466.35 83.48 18.84 9,741.79 6,121.15 1,966.60 6,429.26 2.58 12,561.35 82.66 18.47 9,753.26 6,210.50 1,996.78 6,523.56 0.95 12,656.09 82.91 19.86 9,765.16 6,299.28 2,027.63 6,617.54 1.47 12,751.70 82.41 20.91 9,777.37 6,388.17 2,060.66 6,712.28 1.22 12,846.18 83.10 19.88 9,789.29 6,476.01 2,093.32 6,805.92 1.31 12,940.68 82.85 20.82 9,800.85 6,563.95 2,125.93 6,899.63 1.02 13,035.69 81.97 18.73 9,813.40 6,652.57 2,157.79 6,993.76 2.37 13,130.34 83.04 17.71 9,825.74 6,741.70 2,187.12 7,087.60 1.56 13,225.54 82.41 18.88 9,837.80 6,831.36 2,216.77 7,182.03 1.39 13,320.16 83.35 17.89 9,849.53 6,920.46 2,246.38 7,275.91 1.44 13,414.18 83.66 19.15 9,860.16 7,009.03 2,276.05 7,369.32 1.36 13,508.55 82.35 17.28 9,871.66 7,098.00 2,305.33 7,462.98 2.41 13,636.00 82.35 17.28 9,888.62 7,098.00 2,305.33 7,462.98 2.41 Note: Survey @ 13,636 is a projection to bit depth. TBU M-28RD 35 4.2 BIT RECORD BIT NO. SIZE TYPE S/N JETS/ TFA IN OUT Feet Drilled HRS AVE ROP (Ft/HR) CONDITION Mill 8.5” Window Mill / Baker Oil Tools 12619457 N/A 8,850’ 8,606’ 56’ 6.75 27.3’ — 1 8.5” HDBS MMD75DC 12896354 7x12 / 0.7731 8,606’ 11,296’ 2,690’ 41.25 101.3’ 8-4-RO-C-X-I-WT-PR 2 8.5” HDBS MMD75DC 12896069 7x12 / 0.7731 11,296’ 13,636’ 2,340’ 31.25 113.4’ 1-2-BT-S-X-I-WT-TD TBU M-28RD 36 4.3 Mud Record Contractor: Halliburton Baroid Date Depth MD TVD MW (ppg) VIS (s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) ASG AgNO3 CaCl2 (ppbl) Lime (ppb) ENVIROMUL 5/1/2017 8,550 7,052 8.90 53 15 24 5/5/6 3.8 0/3 7.2 83.0/17.0 0.10 3.185 1.6 18.88 8.81 5/2/2017 8,606 7,095 9.05 53 16 9 9/11/15 3.8 0/3 7.5 82.3/17.7 0.10 3.295 1.8 16.46 8.29 5/3/2017 8,606 7,095 9.05 55 17 9 9/11/15 4.0 0/3 7.5 82.3/17.7 0.10 3.291 1.8 16.94 7.77 5/4/2017 8,606 7,095 9.10 56 18 12 10/15/18 3.4 0/3 7.9 81.1/18.9 0.10 3.223 1.7 13.54 8.29 5/5/2017 10,561 8,962 9.00 57 21 13 10/15/18 3.2 0/3 8.0 81.1/18.9 0.10 3.079 1.6 12.57 8.68 5/6/2017 10,825 9,200 9.00 57 21 12 10/17/22 3.0 0/3 8.1 80.6/19.4 0.10 3.042 1.6 14.51 7.77 5/7/2017 11,296 9,497 9.10 61 23 12 10/17/22 3.2 0/3 8.5 80.7/19.3 0.10 3.064 1.7 14.51 7.12 5/8/2017 12,126 9,487 9.10 56 23 10 10/22/22 3.2 0/3 9.3 80.6/19.4 0.10 2.873 1.6 15.00 7.77 5/9/2017 13,257 9,834 9.15 56 24 10 10/22/24 3.2 0/3 9.2 80.6/19.4 0.10 2.957 1.6 13.06 9.07 5/10/2017 13,636 9,888 9.15 56 19 14 10/22/24 3.2 0/3 9.1 82.0/18.0 0.10 3.037 1.6 13.54 5.83 5/11/2017 13,636 9,888 9.30 87 22 13 10/30/34 3.2 0/3 8.5 81.6/18.4 0.10 3.337 1.6 13.54 5.83 5/12/2017 13,636 9,888 9.50 77 24 13 12/30/34 3.2 0/3 10.6 82.3/17.7 0.10 3.117 1.6 15.00 9.32 5/13/2017 13,636 9,888 9.55 86 28 16 12/30/34 3.2 0/3 10.6 82.3/17.7 0.10 3.185 1.7 13.06 9.84 5/14/2017 13,636 9,888 9.60 92 29 17 13/30/32 3.2 0/3 10.6 82.3/17.7 0.10 3.236 1.7 14.03 9.97 5/15/2017 13,636 9,888 Abbreviations: MW = Mud Weight VIS = Funnel Viscosity PV = Plastic Viscosity YP = Yield Point Gels = Gel Strength FL = Water or Filtrate Loss FC = Filter Cake O/W = Oil to Water ratio Sols = Solids Sd = Sand content MBT = Methylene Blue Alk, Pm = Alkalinity, Mud pH = Acidity Cl = Chlorides Ca = Hardness Calcium nr = Not Recorded TBU M-28RD 37 Drilling Progress 8,000 9,000 10,000 11,000 12,000 13,000 14,000 Days Vs. Depth TBU M-28RD 38 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 8993'MD 9449'MD Country:20 7430'TVD 7874'TVD Averages Before During After Maximum ROP (fph)69 ft/hr 113 ft/hr 123 ft/hr 291 ft/hr WOB 16 klbs 7 klbs 14 klbs 18 klbs RPM 107 rpm 115 rpm 116 rpm 126 rpm PP 1913 psi 1931 psi 1982 psi 2009 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chloride Total Gas 12 105 21 1,032 C1 (ppm)1,743 23,313 3,813 226,899 C2 (ppm)13 3 - 106 C3 (ppm)- 6 - 35 C4 (ppm)- 0 - 3 C5 (ppm)- - - - Lithology Odor none Amount 20%Type slow Amount Amount none Distribution patchy Intensity weak Color Color none Intensity mod/wk Color yellow Color yel/wht Intesity Color none Color Comments Report by: Residual Cut Sandstone (9350' - 9380') = overall light to moderate olive brown to light olive; moderately firm to firm friable, friable; quartz framework with scattered feldspar and calcite, occasional dark lithics; dominantly lower medium to lower fine; moderate to fair sorting; sub-angular to sub-rounded; low to moderate sphericity; grain support with rare calcite cement; occasional carbonaceous material; weak reaction to HCl; even dull yellow sample Hilcorp Alaska, LLC 50-733-20414-01-00TBU M-28RD McArthur River Field Steelhead 51 5/5/2017 4:30 AM Cut Free Oil in Mud Kenai Borough Alaska USA none none Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis none Mike Skiles masked by oil base mud0.5 none Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 10095'MD 11283'MD Country:20 8511'TVD 9492'TVD Averages Before During After Maximum ROP (fph)138 ft/hr 94 ft/hr 37 ft/hr 648 ft/hr WOB 2 klbs 9 klbs 32 klbs 32 klbs RPM 125 rpm 121 rpm 117 rpm 147 rpm PP 2198 psi 2078 psi 2012 psi 2323 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chloride Total Gas 158 49 27 328 C1 (ppm)37,869 9,301 4,367 72,633 C2 (ppm)- 276 455 2,106 C3 (ppm)11 133 70 1,174 C4 (ppm)- 62 28 459 C5 (ppm)- 20 6 119 Lithology Odor none Amount 20%Type slow Amount Amount moderate Distribution patchy Intensity weak Color Color brown Intensity mod/wk Color yellow Color yel/wht Intesity Color none Color Comments Report by: Residual Cut Sand (10260' - 10340') = overall light to medium olive gray to light olive brown; light brown, light olive gray, light green, milky and occasionally transparent individual grains; lower coarse to upper fine grains; sub-rounded to sub-angular, occasionally angular; low to moderate sphericity; moderately poor to fair sorting; dominant quartz framework with scattered dark lithics and trace micas; unconsolidated; grain support with occasional clayey matrix; trace carbonaceous material; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; slow rare oil stain; weak slow yellow streamers; faint yellow cut fluorescence; faint straw visible cut; faint brown residual cut ring; moderate yellow residual cut stain; oil indicators may be influenced by oil based mud. Hilcorp Alaska, LLC 50-733-20414-01-00TBU M-28RD McArthur River Field Steelhead 51 5/7/2017 1:50 AM Cut Free Oil in Mud Kenai Borough Alaska USA faint straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis faint Mike Skiles masked by oil base mud0.5 straw Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #3 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 11416'MD 12351'MD Country:20 9538'TVD 9727'TVD Averages Before During After Maximum ROP (fph)91 ft/hr 134 ft/hr 75 ft/hr 377 ft/hr WOB 20 klbs 15 klbs 15 klbs 39 klbs RPM 134 rpm 140 rpm 126 rpm 157 rpm PP 2336 psi 2462 psi 2376 psi 2624 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chloride Total Gas 29 38 11 120 C1 (ppm)5,439 6,620 1,584 20,840 C2 (ppm)229 412 48 1,512 C3 (ppm)128 231 20 939 C4 (ppm)58 119 9 397 C5 (ppm)9 48 - 128 Lithology Odor none Amount 20%Type slow Amount Amount moderate Distribution patchy Intensity weak Color Color yellow Intensity mod/wk Color yellow Color yel/wht Intesity Color none Color Comments Report by: Residual Cut Sand (10260' - 10340') = overall light to medium olive gray to light olive brown; light brown, light olive gray, light green, milky and occasionally transparent individual grains; lower coarse to upper fine grains; sub-rounded to sub-angular, occasionally angular; low to moderate sphericity; moderately poor to fair sorting; dominant quartz framework with scattered dark lithics and trace micas; unconsolidated; grain support with occasional clayey matrix; trace carbonaceous material; petroleum odor masked by oil based mud; even moderately bright yellow sample fluorescence; slow rare oil stain; weak slow yellow streamers; faint yellow cut fluorescence; faint straw visible cut; faint brown residual cut ring; moderate yellow residual cut stain; oil indicators may be influenced by oil based mud. Hilcorp Alaska, LLC 50-733-20414-01-00TBU M-28RD McArthur River Field Steelhead 51 5/7/2017 1:50 AM Cut Free Oil in Mud Kenai Borough Alaska USA faint straw Stain Fluorescence Cut Fluorescence Residual Fluorescence Cuttings Analysis faint Mike Skiles no0.5 straw Oil Show Rating 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #4 Operator: Well:API Number: Field:Date: Rig:Time: County:Depth Start End State:20 12401'MD 13639'MD Country:20 9733'TVD 9887'TVD Averages Before During After Maximum ROP (fph)129 ft/hr 101 ft/hr 0 ft/hr 321 ft/hr WOB 13 klbs 21 klbs 0 klbs 47 klbs RPM 137 rpm 141 rpm 0 rpm 154 rpm PP 2363 psi 2514 psi 0 psi 2670 psi Mud Weight 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal 0.0 lbs/gal Chloride Total Gas 19 28 - 121 C1 (ppm)3,349 4,527 - 23,260 C2 (ppm)125 382 - 1,766 C3 (ppm)48 192 - 1,108 C4 (ppm)17 91 - 510 C5 (ppm)5 33 - 162 Lithology Odor none Amount 100%Type slow Amount Amount common Distribution even Intensity bright Color Color brown Intensity bright Color yellow Color yellow Intesity Color dark straw Color Comments Report by: Residual Fluorescence Cuttings Analysis bright Mike Skiles / Allen Odegaard masked by oil base mud0.7 yellow Oil Show Rating Cut Free Oil in Mud Kenai Borough Alaska USA bright yellow-white Stain Fluorescence Cut Fluorescence Hilcorp Alaska, LLC 50-733-20414-01-00TBU M-28RD McArthur River Field Steelhead 51 5/10/2017 8:10 AM Residual Cut Sandstone / Conglomerate Sand (13160' - 13260') = overall light to med olive brown to olive gray; clear, milky, light gray, and green individual grains; very coarse to lower medium; poor sorting; very angular to sub-angular, occasional sub-rounded; low sphericity; quartz framework with scattered feldspar and rare micas, dark lithics; unconsolidated; sandstone is lower fine to lower medium; sub-rounded to sub- angular; moderate sphericity; grain support; non calcareous; common oil stain on fresh surface; petro odor masked by oil based mud; moderately bright yellow sample fluorescence; slow moderately bright yellowish white cut fluorescence; dark straw visible cut; moderately bright yellow residual cut fluorescence; medium brown residual cut ring; oil indicators maybe influenced by oil based mud. 1 10 100 1000 10000 1 2 3 4ppmPixler Plot DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 TBU M-28RD 39 6 DAILY REPORTS Hilcorp Alaska, LLC DAILY WELLSITE REPORT M-28RD REPORT FOR S. Hauck / A. Lundale DATE 05/01/2017 DEPTH 9103 PRESENT OPERATION Cleaning pits TIME 23:50:00 YESTERDAY 9103 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Rig up and continue working on Pre-OBM check list, Troubleshoot / Resolve SCR issue, RIH from 83979' to 8545', Clean out mud system, POOH form 8545' to 8492', Rack back stand and single in to 8519', Clean pits for OBM. CANRIG PERSONNEL ON BOARD 3 DAILY COST $3825 REPORT BY M. Skiles Page 1 of 1Daily Report 5/2/2017file:///C:/Users/Canrigadmin/Documents/My%20Wells/Hilcorp/20170502.htm Hilcorp Alaska LLC DAILY WELLSITE REPORT M-28RD REPORT FOR S. Hauck / H. Soule DATE May 02, 2017 DEPTH 8606 PRESENT OPERATION POOH TIME 23:47:27 YESTERDAY 8551 24 HOUR FOOTAGE 55 CASING INFORMATION 10 3/4" @ 467' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 93.5 @ 8600 2.6 @ 8564 27.8 15.94 FT/HR SURFACE TORQUE 18847 @ 8553 13189 @ 8564 15438.9 15314.42 AMPS WEIGHT ON BIT 0 @ 8606 0 @ 8606 0.0 0 KLBS ROTARY RPM 0 @ 8606 0 @ 8606 0.0 0 RPM PUMP PRESSURE 0 @ 8606 0 @ 8606 0.0 0 PSI DRILLING MUD REPORT DEPTH 8606 MW 9.05 VIS 53 PV 16 YP 9 FL 3.8 Gels 9/11/15 CL- FC 0/3 SOL 7.5 SD 0.10 OIL 82.3/17.7 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 93 @ 8603 1 @ 8586 9.4 TRIP GAS CUTTING GAS 0 @ 8606 0 @ 8606 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 40974 @ 8603 25 @ 8552 1601.0 CONNECTION GAS HIGH 197 (POG) ETHANE (C-2) 0 @ 8606 0 @ 8606 0.0 AVG 197 PROPANE (C-3) 0 @ 8606 0 @ 8606 0.0 CURRENT 1.6 BUTANE (C-4) 0 @ 8606 0 @ 8606 0.0 CURRENT BACKGROUND/AVG 1.6 PENTANE (C-5) 0 @ 8606 0 @ 8606 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 50% Coal, 20% Sandstone, 20% Cement, 10% Sand DAILY ACTIVITY SUMMARY Service rig, Clean out mud system for OBM, Circulate and condition mud, Mill window from 8550' to 8567', Drill from 8567' to 8585', FIT to 12.68 EMW, Drill from 8585' to 8606', Circulate and condition hole, POOH CANRIG PERSONNEL ON BOARD 3 DAILY COST $2665 REPORT BY M. Skiles Page 1 of 1Daily Report 5/3/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170502.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR S. Hauck / H. Soule DATE May 03, 2017 DEPTH 8606' PRESENT OPERATION M/U BHA TIME 23:47:27 YESTERDAY 8606' 24 HOUR FOOTAGE 0 CASING INFORMATION 10 3/4" @ 467' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8606' MW 9.05 VIS 55 PV 17 YP 9 FL - Gels 9/11/15 CL- - FC 0/3 SOL 7.5 SD 0.10 OIL 82.3/17.7 MBL - pH - Ca+ -CCI - MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY POOH checking torque on connections, P/U DP, Slip and cut line, Rack back DP, M/U BHA CANRIG PERSONNEL ON BOARD 4 DAILY COST $3065 REPORT BY M. Skiles Page 1 of 1Daily Report 5/4/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170502.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR DATE May 04, 2017 DEPTH 9188' PRESENT OPERATION Drilling ahead TIME 23:51:16 YESTERDAY 8606' 24 HOUR FOOTAGE 582' CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8773.69' 31.25 12.83 7231.08' 8868.60' 25.32 7.14 7314.64' 8962.24' 19.34 3.86 7401.22' 9057.87' 18.75 2.7 7491.61' 9151.86' 14.64 355.7 7581.63' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS MMD75DC 12896354 7x12 8606' 582' 9.96 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 290.9 @ 8994' 0.3 @ 8756' 89.5 114.816 FT/HR SURFACE TORQUE 19735 @ 9065' 2092 @ 9091' 17737.6 19040.38 AMPS WEIGHT ON BIT 9 @ 8629' 0 @ 8606' 1.3 0.00000 KLBS ROTARY RPM 101 @ 8606' 101 @ 8606' 0.2 0.00000 RPM PUMP PRESSURE 2022 @ 8627' 1576 @ 8786' 1891.4 1938.25 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8606' TO 9188' TOOLS Rotary steerable + MWD + LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 338 @ 9044' 3 @ 8682' 43.0 TRIP GAS 33 CUTTING GAS 0 @ 9188' 0 @ 9188' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 78562 @ 9045' 273 @ 8677' 9215.2 CONNECTION GAS HIGH - ETHANE (C-2) 105 @ 9067' 1 @ 8818' 4.1 AVG - PROPANE (C-3) 29 @ 9045' 0 @ 8901' 3.1 CURRENT 6 BUTANE (C-4) 3 @ 9041' 3 @ 9043' 0.0 CURRENT BACKGROUND/AVG 4 PENTANE (C-5) 0 @ 9188' 0 @ 9188' 0.0 HYDROCARBON SHOWS moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9000-9100 Sand/Sandstone Max 338u occ oil stain, mod yllw smp fluor, tr free oil fresh surface, fst brt whtish yllw cut fluor, straw vis cut, mod brt yllw resid cut fluor. LITHOLOGY Tyonek PRESENT LITHOLOGY 40% Siltstone, 20% Tuffaceous claystone, 20% Claystone, 10% Carbonaceous shale, 10% Sand DAILY ACTIVITY SUMMARY M/U BHA, RIH t/ 2649', Circulate, RIH f/ 2649' t/ 4544', Circulate, RIH f/ 4544' t/ 6439', Circulate, RIH f/ 6439' t/ 8525', Circulate and condition, Drill f/ 8606' t/ 9188' CANRIG PERSONNEL ON BOARD 5 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/5/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170504.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT M-28RD REPORT FOR E. Harness / H. Soule DATE May 05, 2017 DEPTH 10560' PRESENT OPERATION Drilling ahead TIME 23:58:26 YESTERDAY 9188' 24 HOUR FOOTAGE 1372' CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9246.54' 9.39 338.94 7674.23' 9437.15' 10.0 349.64 7862.46' 9720.25' 8.88 348.36 8141.52' 10098.04' 9.43 349.34 8513.63' 10382.97' 12.96 346.09 8793.46' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS MMD75DC 12896354 7x12 8606' 2010' 23.8 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 647.7 @ 10553' 5.9 @ 9378' 122.3 43.58147 FT/HR SURFACE TORQUE 22280 @ 9744' 15477 @ 10421' 19389.1 17206.79688 AMPS WEIGHT ON BIT 0 @ 10560' 0 @ 10560' 0.0 0.00000 KLBS ROTARY RPM 0 @ 10560' 0 @ 10560' 0.0 0.00000 RPM PUMP PRESSURE 2253 @ 9960' 1566 @ 9610' 2063.7 2180.44946 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8550' TO 10560' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1032 @ 9266' 10 @ 9761' 82.3 TRIP GAS CUTTING GAS 0 @ 10560' 0 @ 10560' 0.0 WIPER GAS 72u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 226899 @ 9266' 1228 @ 9391' 18036.3 CONNECTION GAS HIGH ETHANE (C-2) 825 @ 10431' 4 @ 9374' 52.2 AVG PROPANE (C-3) 639 @ 10431' 0 @ 9216' 39.7 CURRENT 14 BUTANE (C-4) 321 @ 10431' 3 @ 9980' 17.2 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 82 @ 10431' 4 @ 10495' 4.1 HYDROCARBON SHOWS moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9200-10560 Sand / Sandstone 100- 350u even dl yllw smp flr, oil odor masked by obm, mod brt whtish yllw cut flr, fnt straw to lt brn vis cut, fnt brn res cut ring, mod brt yllw res flr LITHOLOGY Tyonek PRESENT LITHOLOGY 40% Sand, 30% Sandstone, 10% tuffaceous sandstone, 10% carbonaceous shale, 10% tuffaceous claystone DAILY ACTIVITY SUMMARY Drill f/ 9188' t/ 10036', Wipe hole to 9176', RIH to bottom, Circulate 2 B/U (72u Max Gas), Drill f/ 10036' t/ 10560'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/6/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170505.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 06, 2017 DEPTH 11272' PRESENT OPERATION Drilling ahead TIME 23:54:02 YESTERDAY 10560' 24 HOUR FOOTAGE 712 CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10477.69' 16.55 355.15 8885.06' 10668.03' 23.42 5.56 9063.46' 10856.33' 36.45 7.83 9226.34' 11046.29' 49.45 12.89 9365.50' 11237.79' 63.09 14.66 9473.24' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS MMD75DC 12896354 7X12 8606' 2666' 40.1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 206.7 @ 10636' 1.7 @ 11270' 72.7 63.315 FT/HR SURFACE TORQUE 24068 @ 11005' -2 @ 11081' 20061.0 23.260 AMPS WEIGHT ON BIT 0 @ 11272' 0 @ 11272' 0.0 0.00000 KLBS ROTARY RPM 0 @ 11272' 0 @ 11272' 0.0 0.00000 RPM PUMP PRESSURE 2323 @ 11171' 0 @ 11081' 2023.9 0.32993 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8606' TO 11272' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 143 @ 10811' 5 @ 10710' 33.3 TRIP GAS CUTTING GAS 0 @ 11272' 0 @ 11272' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 24549 @ 10810' 92 @ 10726' 5208.2 CONNECTION GAS HIGH - ETHANE (C-2) 2105 @ 10812' 5 @ 10712' 363.6 AVG - PROPANE (C-3) 1173 @ 10812' 2 @ 10718' 152.2 CURRENT 14 BUTANE (C-4) 458 @ 10812' 3 @ 10685' 70.7 CURRENT BACKGROUND/AVG 12 PENTANE (C-5) 118 @ 10810' 1 @ 10631' 24.9 HYDROCARBON SHOWS moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10560' -11272' Sand, Sandstone 50- 143u ev dl yllw smpl flr, mod brt whtsh yllw cut flr, lt brn to drk strw vis cut, fnt brn res cut ring, mod brt yllw res cut flr, odor msked by obm LITHOLOGY Hemlock PRESENT LITHOLOGY 40% Sand, 30% Sandstone, 10%Conglomerate Sand, 10% Tuffaceous Claystone, 10% Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Drill f/ 10560' t/ 11272' CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/7/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170506.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT M-28RD REPORT FOR E. Harness / H. Soule DATE May 07, 2017 DEPTH 11296' PRESENT OPERATION RIH TIME 23:59:21 YESTERDAY 11272' 24 HOUR FOOTAGE 24 CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7x12 11296' 2 8.5" HDBS MMD75DC 12896354 7X12 8606' 11296' 2690' 41.25 8,4,R,O,C,X,I,W,T,P,R DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 68.1 @ 11278' 3.1 @ 11296' 41.7 3.062 FT/HR SURFACE TORQUE 22260 @ 11292' 16919 @ 11296' 21278.6 16919.834 AMPS WEIGHT ON BIT 0 @ 11296' 0 @ 11296' 0.0 0.00000 KLBS ROTARY RPM 0 @ 11296' 0 @ 11296' 0.0 0.00000 RPM PUMP PRESSURE 2023 @ 11272' 1571 @ 11295' 2055.5 1971.831 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8606' TO 11296' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 37 @ 11294' 12 @ 11275' 27.3 TRIP GAS CUTTING GAS 0 @ 11296' 0 @ 11296' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 5814 @ 11294' 1044 @ 11275' 3851.7 CONNECTION GAS HIGH ETHANE (C-2) 742 @ 11294' 16 @ 11296' 414.1 AVG PROPANE (C-3) 118 @ 11294' 9 @ 11296' 75.4 CURRENT 3.5 BUTANE (C-4) 57 @ 11279' 23 @ 11287' 36.4 CURRENT BACKGROUND/AVG 14 PENTANE (C-5) 28 @ 11295' 5 @ 11286' 9.1 HYDROCARBON SHOWS moderately weak INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11272' - 11296' Sand/ Sandstone / Conglomerate sand 20-40 dl yllw smpl flr, mod wk yllw cut flr, odor masked by obm, fnt brn vis cut. LITHOLOGY Hemlock PRESENT LITHOLOGY 40% Sand, 30% Sandstone, 10% Conglomerate sand, 10% tuffaceous sandstone, 10% Tuffaceous claystone DAILY ACTIVITY SUMMARY Drill from 11272' to 11296', Circulate and condition hole, POOH, CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/8/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170507.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 08, 2017 DEPTH 12130' PRESENT OPERATION Drilling ahead TIME 23:06:53 YESTERDAY 11296' 24 HOUR FOOTAGE 834' CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11331.93' 68.09 14.75 9512.13' 11521.11' 75.55 9.69 9565.97' 11710.57' 75.1 9.22 9613.97' 11894.19' 78.16 10.4 9658.50' 12087.81' 81.98 11.92 9690.31' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7X12 11296' 834' 9.38 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 377.0 @ 12096' 1.1 @ 11297'' 133.4 110.986 FT/HR SURFACE TORQUE 26425 @ 12025' 16919 @ 11296' 22317.6 21851.720 AMPS WEIGHT ON BIT 43 @ 11363' 0 @ 11665' 19.3 13.246 KLBS ROTARY RPM 153 @ 12124' 109 @ 11312' 138.6 143.366 RPM PUMP PRESSURE 2624 @ 12079' 1968 @ 11425' 2445.5 2463.908 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8606' TO 12130' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 119 @ 11664' 10 @ 11779' 38.8 TRIP GAS 686u CUTTING GAS 0 @ 12130' 0 @ 12130' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 20840 @ 11717' 962 @ 11779' 6919.8 CONNECTION GAS HIGH - ETHANE (C-2) 1512 @ 11717' 16 @ 11365' 428.1 AVG - PROPANE (C-3) 939 @ 11717' 5 @ 11365' 226.0 CURRENT 11u BUTANE (C-4) 396 @ 11719' 3 @ 11364' 112.2 CURRENT BACKGROUND/AVG 13u PENTANE (C-5) 127 @ 11718' 3 @ 11778' 41.4 HYDROCARBON SHOWS moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11296' - 12130' Sand / Sandstone 25- 50 even mod brt yllw smp flr, mod white yllw cut flr, med straw vis cut, mod yllw res cut flr, lght brn resid cut ring. LITHOLOGY West Foreland PRESENT LITHOLOGY 60% Sand, 30% Sandstone, 10% Tuffaceous Sandstone DAILY ACTIVITY SUMMARY POOH, C/O Bit, RIH to bottom with no issues (Max gas 686u), Drill ahead from 11296' to 12130' CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/9/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/20170509.... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 09, 2017 DEPTH 13261' PRESENT OPERATION Drilling ahead TIME 23:35:59 YESTERDAY 12130' 24 HOUR FOOTAGE 1131' CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12278.59' 81.91 14.85 9716.88' 12466.35' 83.48 18.84 9741.79' 12751.70' 82.41 20.91 9777.37' 13035.69' 81.97 18.73 9813.40' 13225.54' 82.41 18.88 9837.80' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7X12 11296' 1965' 25.36 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 320.7 @ 13170' 0.7 @ 12307' 110.4 61.268 FT/HR SURFACE TORQUE 25863 @ 12363' 18524 @ 12310' 22755.0 20867.423 AMPS WEIGHT ON BIT 45 @ 13171' 0 @ 12524' 16.6 30.248 KLBS ROTARY RPM 156 @ 12340' 108 @ 12362' 140.3 138.291 RPM PUMP PRESSURE 2664 @ 13062' 1937 @ 12648' 2499.3 2517.981 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8606' TO 13261' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 120 @ 12471' 5 @ 12599' 30.3 TRIP GAS CUTTING GAS 0 @ 13261' 0 @ 13261' 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 23259 @ 12472' 440 @ 12925' 5155.0 CONNECTION GAS HIGH - ETHANE (C-2) 1766 @ 12473' 26 @ 12702' 367.4 AVG - PROPANE (C-3) 1108 @ 12473' 11 @ 12353' 205.6 CURRENT 8.7 BUTANE (C-4) 509 @ 12473' 5 @ 12355' 100.4 CURRENT BACKGROUND/AVG 12 PENTANE (C-5) 161 @ 12475' 2 @ 13121' 37.7 HYDROCARBON SHOWS moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 12130' - 13261' Conglomerate sand / Sand / Sandstone 20-50 occ oil stain, yllw smpl flr, mod brt yllw cut flr, lt brn vis cut, yllw resid cut flr. LITHOLOGY West Foreland PRESENT LITHOLOGY 50% Conglomerate sand, 30% Sandstone, 10% Sand, 10% Tuffaceous Sandstone DAILY ACTIVITY SUMMARY Drill ahead from 12130' to 13261'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/10/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/2017050... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 10, 2017 DEPTH 13636' PRESENT OPERATION POOH TIME 23:55:53 YESTERDAY 13261' 24 HOUR FOOTAGE 375' CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13320.16' 83.35 17.89 9849.53' 13414.18' 83.66 19.15 9860.16' 13636' (Proj) 82.35 17.28 9888.62' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7X12 11296' 13636' 2340' 31.23 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 136.6 @ 13285' 6.1 @ 13515' 78.0 78.132 FT/HR SURFACE TORQUE 25222 @ 13274' 20015 @ 13301' 23623.1 23931.824 AMPS WEIGHT ON BIT 46 @ 13263' 5 @ 13565' 24.0 15.887 KLBS ROTARY RPM 154 @ 13286' 127 @ 13580' 141.9 136.623 RPM PUMP PRESSURE 2670 @ 13603' 2074 @ 13605' 2497.5 2326.194 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 8606' TO 13636' TOOLS Rotary Steerable + MWD/LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 80 @ 13284' 10 @ 13523' 19.0 TRIP GAS CUTTING GAS 0 @ 13636' 0 @ 13636' 0.0 WIPER GAS 55u CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 13969 @ 13284' 1029 @ 13302' 2693.5 CONNECTION GAS HIGH - ETHANE (C-2) 1549 @ 13284' 97 @ 13302' 335.0 AVG - PROPANE (C-3) 882 @ 13284' 27 @ 13524' 124.0 CURRENT 3u BUTANE (C-4) 339 @ 13284' 12 @ 13524' 57.5 CURRENT BACKGROUND/AVG 8u PENTANE (C-5) 101 @ 13286' 3 @ 13533' 23.9 HYDROCARBON SHOWS moderate INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 13261' - 13636' Conglomerate sand / sandstone / Tuffaceous sandstone 30- 80 yllw smp flr, brt yllwish wht cut flr w/ slw brt yllw streamrs, lt straw vis cut, com oil stain, fnt brwn res cut ring, mod yllw res cut flr. LITHOLOGY West Foreland PRESENT LITHOLOGY 30% Conglomerate Sand, 30% Tuffaceous Sandstone, 10% Sand, 10% Sandstone, 10% Tuffaceous Claystone, 10% Tuffaceous Shale. DAILY ACTIVITY SUMMARY Drill from 13261' to 13636', POOH to 9851' due to pump pressure loss, Lay down washed out pipe, RIH to 12408', Circulate and condition, Started packing off, Worked torque down to bit, reestablished circulation, Circulate and condition, POOH. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/11/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/2017051... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 11, 2017 DEPTH 13636' PRESENT OPERATION Testing BOPs TIME 23:55:53 YESTERDAY 13636 24 HOUR FOOTAGE 0 CASING INFORMATION 10 3/4" @ 497' 9 5/8" @ 8550' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7x12 11296' 13636' 2340' 31.23 1-2-BT-S-X-I-WT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY 30% Conglomerate sand, 30% Tuffaceous sandstone, 10% Sand, 10% Tuffaceous Claystone, 10% Tuffaceous Shale DAILY ACTIVITY SUMMARY POOH, Circulate at KOP (Max gas 10u), POOH and L/D directional tools and bit, Test BOPs CANRIG PERSONNEL ON BOARD 4 DAILY COST $3510 REPORT BY M. Skiles Page 1 of 1Daily Report 5/11/2017file:///C:/USERS/CANRIGADMIN/DOCUMENTS/MY%20WELLS/HILCORP/2017051... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 12, 2017 DEPTH 13636' PRESENT OPERATION Circulate and condition mud TIME 23:55:53 YESTERDAY 13636 24 HOUR FOOTAGE 0 CASING INFORMATION ..........10 3/4" @ 497' ..........9 5/8" @ 8550'__(Window 8550'-8567') ..........7" @ SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13508.55 82.35 17.28 9871.66 Projected 13636.00 82.35 17.28 9888.62 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7x12 11296' 13636' 2340' 31.23 1-2-BT-S-X-I-WT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT/LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 72 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 329u @ 13636' @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 8.6u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY 30% Conglomerate sand, 30% Tuffaceous sandstone, 10% Sand, 10% Tuffaceous Claystone, 10% Tuffaceous Shale DAILY ACTIVITY SUMMARY Complete testing BOPs, M/U Clean out assembly, RIH to 8515' above window, Circulate and conditon mud, Slip and Cut 105' drill line, Continue to RIH, Ream tight spots as needed, Circulate out gas during reaming at 11350'= Max trip gas of 329u at depth. Continue to ream tight spots @ 11670'= gas up to 205u. Continue to Ream from 12500' to bottom (13636'). Average background gas from tight spot @ 12,500' was 14.3u. Continue to circulate and condition mud at report time. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3560 REPORT BY Marquel Mosebay Page 1 of 1Daily Report 5/13/2017file:///C:/Users/Canrigadmin/Documents/My%20Wells/Hilcorp/AM%20Re... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 13, 2017 DEPTH 13636' PRESENT OPERATION POOH for 7" Liner TIME 23:59:57 YESTERDAY 13636 24 HOUR FOOTAGE 0 CASING INFORMATION ..........10 3/4" @ 497' ..........9 5/8" @ 8550'__(Window 8550'-8567') ..........7" Liner @ SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13508.55 82.35 17.28 9871.66 Projected 13636.00 82.35 17.28 9888.62 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7x12 11296' 13636' 2340' 31.23 1-2-BT-S-X-I-WT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT/LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 77 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS 47.2 @ 11500' 36.3 @ 13550 TRIP GAS @ WIPER GAS 47u @ 11500' CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 1.4u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY 30% Conglomerate sand, 30% Tuffaceous sandstone, 10% Sand, 10% Tuffaceous Claystone, 10% Tuffaceous Shale DAILY ACTIVITY SUMMARY Continue to circulate and condition mud, "pump sweeps", spot lube pill, POOH from 13636' to 10500', Work through tight spots 12890' to 10600', Trip in Hole, Wash through tight spots at 11500', Max wiper gas = 45u, Note=collected sample at depth, majority of sample was sand, Continue to Trip in Hole, circulate and work pipe at 13550' to bottom;(gas = 36u), Circulate, POOH, Trip pipe out of hole to 8472', break circulation, pump a dry job, Continue to POOH. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2665 REPORT BY Marquel Mosebay Page 1 of 1Daily Report 5/14/2017file:///C:/Users/Canrigadmin/Documents/My%20Wells/Hilcorp/20170513.h... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 14, 2017 DEPTH 13636' PRESENT OPERATION: RUN 7" LINER on 5" DP TIME 23:59:57 YESTERDAY 13636 24 HOUR FOOTAGE 0 CASING INFORMATION ..........10 3/4" @ 497' ..........9 5/8" @ 8550'__(Window 8550'-8567') ..........7" Liner @ SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13508.55 82.35 17.28 9871.66 Projected 13636.00 82.35 17.28 9888.62 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7x12 11296' 13636' 2340' 31.23 1-2-BT-S-X-I-WT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT/LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 77 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS 7.8 @ 5442 2.1 @ 5345 TRIP GAS @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 4.8u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY 30% Conglomerate sand, 30% Tuffaceous sandstone, 10% Sand, 10% Tuffaceous Claystone, 10% Tuffaceous Shale DAILY ACTIVITY SUMMARY Continue to POOH from 3040’, POOH to surface, R/U Casing tools and equipment, Run 7" Liner to depth, Run hanger tool, Continue to Run Liner on 5" DP, Filling pipe with mud pumps every 10 stands, Continue running 7" Liner on 5" DP at report time. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2665 REPORT BY Marquel Mosebay Page 1 of 1Daily Report 5/15/2017file:///C:/Users/Canrigadmin/Documents/My%20Wells/Hilcorp/20170514.h... Hilcorp Alaska LLC Trading Bay Unit DAILY WELLSITE REPORT TBU M-28RD REPORT FOR E. Harness / H. Soule DATE May 15, 2017 DEPTH 13636' PRESENT OPERATION: COMPLETED CEMENT JOB TIME 23:59:57 YESTERDAY 13636 24 HOUR FOOTAGE 0 CASING INFORMATION ..........10 3/4" @ 497' ..........9 5/8" @ 8550'__(Window 8550'-8567') ..........7" Liner @ 13636' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 13508.55 82.35 17.28 9871.66 Projected 13636.00 82.35 17.28 9888.62 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" HDBS MMD75DC 12896069 7x12 11296' 13636' 2340' 31.23 1-2-BT-S-X-I-WT TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ FT/LBS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 9.6 VIS 92 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE CIRCULATING GAS @ @ TRIP GAS 202 units @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2.8 units PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY West Foreland PRESENT LITHOLOGY 30% Conglomerate sand, 30% Tuffaceous sandstone, 10% Sand, 10% Tuffaceous Claystone, 10% Tuffaceous Shale DAILY ACTIVITY SUMMARY Continue to Run 7" Liner on 5" DP, filling pipe with mud pumps every 10 stands, to 11600, circulate out gas, Max Trip Gas = 202units, Continue to run 7" Liner to bottom, working pipe through various tight spots from 11600' to 16336', Circulate and condition stage pumps for cement job. Held PJSM before cementing 7" Liner in place, Completed Cement job of 7" Liner String @ 13636'. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2665 REPORT BY Marquel Mosebay Page 1 of 1Daily Report 5/16/2017file:///C:/Users/Canrigadmin/Documents/My%20Wells/Hilcorp/20170515.h...
